Highly flexible, electrical distribution grid edge energy manager and router

ABSTRACT

An electrical distribution grid energy management and router device, or GER device, may be installed in a distribution grid, and route power from power supply to one or more power consumers. The GER devices described herein may provide platforms to add one or more features to a distribution transformer, provide additional features and benefits to both the utility company and end consumer, and may serve as a platform for providing other features. A GER device may include sensors to measure electrical properties of incoming and outgoing power, and may include an electrical circuit layer having a central DC power stage. A GER device may include a physical layer providing a communications platform for one or more communication devices that may communicate with other GER devices to form a micro-grid, a utility, power consumers, third parties, and other electrical devices.

RELATED APPLICATIONS

This application claims the benefit of International ApplicationPCT/US2015/22979, filed Mar. 27, 2015, which claims priority to U.S.Provisional Application No. 62/015,703 filed on Jun. 23, 2014; andclaims priority to International Application PCT/US2015/043396, filedAug. 3, 2015, which claims priority to U.S. Provisional Application No.62/032,186 filed on Aug. 1, 2014, each of which is hereby incorporatedby reference in its entirety.

STATEMENT REGARDING GOVERNMENT SUPPORT

None

FIELD

This application relates to devices, systems, and methods for electricaldistribution grid edge energy management and routing.

BACKGROUND

Advanced power delivery is essential to meeting the growing demand forpower distribution. Power consumers expect safe and reliableelectricity, and the generation and consumption of power is increasinglymonitored, analyzed, scrutinized, and reported. Further, theenvironmental effects of the worldwide increase in energy demand arealarming, raising the need for enhanced efficiency in not only powergeneration, but also power distribution and use. Power delivery systemsneed to evolve. Today's electrical grid, for example, was designed for aless-demanding consumer, in a less-demanding time, and for asignificantly less-demanding purpose.

Consumers' steady adoption of new energy-related technology has thepotential to reduce the price of adopting and exposing weaknesses in thefragile electrical distribution grid. The power distribution grid, whichmay also be referred to as the grid, was designed over a century ago.The grid was designed without anticipating the need to accommodate solarpanels, wind turbines, electric vehicles, energy storage, and many otherdevices. Simultaneously, consumer intolerance for extended outages hasgrown, efficiency mandates are numerous, and traditional generationpractices are being scrutinized. A need for a modernized grid exists

The power distribution substation is, in most distribution grids, thelast point of “energy traffic control” before electricity is sentdownstream to thousands of consumers. The growing emphasis on generationemissions and pressures to reduce carbon footprints necessitatesystem-wide efficiency gains, and exposed the limitations of thedistribution grid and substation design. Because utilities (i.e., powerproviders) are able to control distribution only up to a powersubstation, utilities are limited on achievable efficiency gains in theoverall grid. Furthermore, centralized software platforms approachpromised some degree of improved efficiency and load management, but therequired a complicated complementary environment and supportinginfrastructure not heretofore seen. Modernizing the distribution grid inthis fashion will create the growing need for an immense communicationsbandwidth, extensive centralized processing power, numerous functioningdownstream sensors, and intelligent hardware able to enact organizedadjustments on a granular scale.

The distribution transformer is an example of a grid edge component withlimited usefulness in a modernized grid. Electric utility systemstypically distribute power using transmission and distribution networks.High voltage (e.g., 69 kV and above) transmission networks are used toconvey power from generating stations to substations that feed lowervoltage (e.g., 35 kV and below) distribution networks that are used tocarry power to homes and businesses. In a typical distribution networkused in residential areas, for example, a 7.2 kV single-phasedistribution line may be run along a street, with individual residencesbeing fed via respective service drops from distribution transformersthat step down the voltage to a 120/240V service level. The electricaldistribution system in the United States, for example, includes millionsof such distribution transformers.

The edge of most modern electrical distribution networks or grids, e.g.,the grid location just before demarcation to an end customer, orupstream of a power meter, is represented by a distribution transformerperforming the last voltage reduction to the customer's consumed voltage(usually 100-600 Vac). Although conventional distribution transformersare rugged and relatively efficient devices, they generally have limitedcontrol capabilities. For example, the impedance of the load connectedto a distribution transformer typically dictates reactive power flowthrough the transformer, as typical conventional distributiontransformers have no ability to control reactive power flow. Inaddition, while traditional distribution transformers can be enhanced toadjust voltage provided to the load using mechanisms such as tapchangers, such capabilities are typically more expensive and seldomused, and typically cannot effectively regulate the load voltage in realtime to compensate for transient sags and spikes. Conventionaldistribution transformers also typically have no capability tocompensate for harmonics introduced by non-linear loads. Hybridtransformers that may address some of these issues are described in U.S.Pat. No. 8,013,702 to Haj-Maharsi et al., U.S. Patent ApplicationPublication No. 2010/0220499 to Haj-Maharsi et al., U.S. PatentApplication Publication No. 2010/0201338 to Haj-Maharsi et al. and thearticle by Bala et al. entitled “Hybrid Distribution Transformer:Concept Development and Field Demonstration,” IEEE Energy ConversionCongress & Exposition, Raleigh, N.C. (Sep. 15-20, 2012). However,today's distribution transformer has no intelligent computing sub-systemand is essentially a simple, one-function, passive component.

The limitations of the transformer are only one example of the hurdlesfacing a modernized distribution grid. Today's grid also has a limitedability to integrate renewable power generation, as can be seen by thenumber of consumers seeking to integrate sources such as photovoltaic(PV) systems, and the correlated mandates to connect such devices to thegrid. The distribution grid was originally designed for largecentralized generation facilities and power flow in one direction—to theconsumer. Unfortunately, centralized generation can neither sync withhundreds of power sources nor accommodate their variability. Althoughutilities have experimented with various energy storage solutions, thereis still a need for an intelligent orchestration of power flow betweenthe generation, storage, and load.

The outdated distribution grid and lack of intelligent grid componentsis also apparent from the broad societal effects of extended outages.Power outages often result from an inability to sectionalize smallerportions of the grid, and reroute power to the healthy sections in anintelligent and controlled manner. Grid reliability and resilience areprincipal initiatives at many utilities. The distribution gridlimitations described above will continue to hinder these initiatives.Traditional utility equipment, grid assets, and supporting distributionand routing methodology, will not be enough to enable such initiatives.What is needed is a new generation of versatile equipment with advancedcapabilities is imperative to permit utilities to meet regulatorymandates, remain competitive, and evolve with customer needs.

SUMMARY

What is needed is the introduction of intelligent and adaptablecapabilities in the power distribution grid, and preferably at the gridedge at either the consumer's location or the distribution transformer,downstream of the substation. Similarly, what is needed is theintroduction of granular power control at key intersections throughoutthe grid. Described herein are devices, systems, and methods thatcombine innovative power electronics-based devices with advancedsoftware and communications capabilities.

Described herein are electrical distribution grid edge energy managerand router devices, generally referred to as the “GER device,” andsystems and methods to utilize embodiments of GER devices in the powerdistribution grid for efficient power distribution, routing, andmanagement. Embodiments of the GER device support ongoing power systemevolution, such as by empowering utilities and consumers to achievemultiple objectives simultaneously with the power delivery system.Embodiments of the GER device may integrate renewable generation,significantly increase distribution efficiency, optimize distributionelectricity flow, and increase overall grid reliability and resilience,through one or more of the features and methods described herein.

In some embodiments, end users of embodiments of the GER device may beutilities, including power generation companies, power distributioncompanies, operators of power substations and/or distributiontransformers, generation locations, and ultimate users of the GERdevice. In this disclosure, the term consumer generally and broadlyrefers to the recipient and/or user of electrical power from a powerdistribution grid, such as, for example, a home owner, a building owneror operator, an institution or facility, and typically (but not always)will be customers of a utility company.

Numerous embodiments of a GER device are possible. The followingdescription is in no way intended to be limiting with respect to thescope of the disclosure. For example, a GER device may include a primaryelectrical connection terminal for receiving power, and at least onesecondary electrical connection terminal for supplying power. Power maybe received, for example, from an electrical grid power supply, such asa power distribution transformer or a power substation. The GER devicemay provide power to, for example, a consumer electrical supply line,such as a supply line providing power to a consumer premise. The GERdevice may include a modular electrical circuit layer. The modularelectrical circuit layer may include one or more circuits as describedbelow. For example, the modular circuit layer may include a powerprocessing circuit for receiving power from the primary electricalconnection terminal and providing power from the central DC stage to atleast one of the at least one secondary electrical connection terminal.

In some embodiments, the modular circuit layer may include a central DCpower stage. The power processing circuit may be configured to convertpower received at the central DC power stage to DC power, and to convertDC power exiting the central DC stage to AC power. A central DC powerstage may advantageously allow for incorporating power supplied by ACpower sources and DC power sources. A central DC power stage may alsoallow for providing power to AC power loads and DC power loads. Acentral DC power stage may also allow for AC phase synchronization.

Embodiments of the GER device may include a controller layer configuredto control other features, functions, components, and/or layers of theGER device. For example, a controller layer may control the modularelectrical circuit layer. The controller layer may include one or morecomputer processors and non-volatile memory, and may be configured torun one or more algorithms as described in more detail below. Algorithmsmay include, for example only, internal status algorithms, grid eventmanagement algorithms, power distribution algorithms, algorithms formanaging reactive power, safety protocols, internal bypass algorithms,cooling and heat management algorithms, cold start protocols, micro-gridformation and management protocols. One of ordinary skill shouldrecognize that numerous algorithms may be developed and used to enablethe features and functions described below, with respect to both asingle GER device and also a micro-grid formed from more than one GERdevice.

Embodiments of the GER device may include a physical layer comprising,for example, one or more communication devices. The physical layer maybe configured to provide one or more communications services, throughone or more communication devices. A communication device may be inoperable communication with the controller layer. In some embodiments, acommunication device may communicate with one or more of an end user,such as a utility, a consumer, and other GER devices.

Embodiments of the GER device may include one or more bi-directional DCpower connection ports. A DC power connection port may be configured forelectrical communication with a DC power resource, and may be inelectrical communication with a central DC power stage. For example, aDC power connection port may provide DC power to or from a central DCpower stage.

Embodiments of the GER device may include one or more AC powerconnection ports. An AC power connection port may be configured forelectrical communication with an AC power source, and may be inelectrical communication with an AC-to-DC power converter. The AC-to-DCpower converter, in turn, may be in electrical communication with thecentral DC stage. In some embodiments, the GER device may receive powerfrom and/or supply power to AC power devices and DC power devices.

Embodiments of the GER device may contain one or more sensors forsensing various parameters. For example, sensors may monitor at leastone of voltage, current, power quality, and device load. Sensor may beused to monitor the primary electrical connection, secondary electricalconnections, and various stages, circuits, components, and layers withina GER device.

In some embodiments, a GER device may use one or more sensors inconnection with distributing power, monitoring loads, and adjusting forpower quality, for example. Embodiments of the GER device may include aPower Quality Meter, which may be a physical device or a virtual device,for measuring power quality of the primary electrical terminal and theat least one secondary electrical terminal. Embodiments of the GERdevice may include a virtual AMI meter, for measuring load on the GERdevice. In some embodiments, the GER device may measure load on one ormore consumers receiving power from the GER device. For example, a GERdevice may include one or more current sense connection sockets forcurrent sense cables that monitor electrical parameters on a secondaryelectrical connection terminal or supply line.

A GER device may be configured for mounting on a pole, on a transformerpad, and/or on a building or consumer location. For example, a GERdevice may include an outer enclosure enclosing at least a portion ofthe GER device, and the enclosure may be configured for mounting on atleast one of a pole, a pad, and a building. Embodiments of the GERdevice may include one or more heat sinks.

Embodiments of the GER device may include a variety of communicationsdevices, features, and functionality. A GER device may communicate withother GER devices, an end user, a consumer, third parties, and otherelectrical devices, for example. For instance, a GER device may includea communications link configured to receive data indicative of at leastone of power provided to at least one consumer, and power demanded by atleast one consumer.

Embodiments of the GER device may include a Power Factor Correctionstage and a Voltage Regulation stage. Some embodiments may include atleast one harmonics filter.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 illustrates an embodiment of an electrical distribution grid edgeenergy manager and router device.

FIG. 2 illustrates an example of a pole-mounted embodiment of anelectrical distribution grid edge energy manager and router device.

FIG. 3 shows a schematic of an embodiment of one possible bracket forpole mounting embodiments from (a) the front, (b) the side, and (c) thetop of the embodiment.

FIGS. 4 and 5 illustrate pad-mounted embodiments of an electricaldistribution grid edge energy manager and router device.

FIG. 6 shows an embodiment of an electrical distribution grid edgeenergy manager and router device mounted on a power consumer's premises.

FIG. 7 illustrates an embodiment of an electrical distribution grid edgeenergy manager and router device integrating AMI features for aplurality of power consumers.

FIG. 8 illustrates an embodiment of an electrical distribution grid edgeenergy manager and router device operating as a virtual PQM and virtualAMI meter.

FIG. 9 shows demonstrative communication features for an embodiment ofan electrical distribution grid edge energy manager and router device.

FIG. 10 is a flow chart for an embodiment of a grid event managementmethod.

FIG. 11 is a flow chart showing an embodiment of an internal statusmonitoring method.

FIG. 12 illustrates an embodiment of an electrical distribution gridedge energy manager and router device measuring current drop for aplurality of power consumers.

FIG. 13 shows an electrical diagram for an embodiment of abi-directional DC connection port included in an embodiment of anelectrical distribution grid edge energy manager and router device.

FIG. 14 illustrates the use of an embodiment of a bi-directional DCconnection port with a power storage device.

FIG. 15 shows an embodiment of integrating DC-based loads into anembodiment of an electrical distribution grid edge energy manager androuter device.

FIG. 16 illustrates an embodiment of an electrical distribution gridedge energy manager and router device monitoring local electricalinfrastructure components.

FIG. 17 shows (a) voltage reduction from electrical losses, (b)traditional voltage regulation methodology, and (c) an embodiment ofvoltage regulation according to methods described herein.

FIG. 18 shows the management of reactive power loads.

FIG. 19 illustrates frequency synchronization in an embodiment of anelectrical distribution grid edge energy manager and router device.

FIG. 20 shows an embodiment of an electrical distribution grid edgeenergy manager and router device operating as a platform forcommunication services.

FIG. 21 is a flow chart of an embodiment of a multi-stage safetyprotocol.

FIG. 22 is an electrical circuit diagram showing an internal bypass inan embodiment of an electrical distribution grid edge energy manager androuter device.

FIG. 23 shows (a) an embodiment of a method for heat management, and (b)and (c) show an embodiment of an electrical distribution grid edgeenergy manager and router device using distribution lines as additionalheat sinks.

FIG. 24 illustrates an embodiment of an electrical distribution gridedge energy manager and router device incorporating a voltage conversionfunction.

FIG. 25 shows an embodiment of an electrical distribution grid edgeenergy manager and router device having an advanced cooling package.

FIG. 26 shows a schematic for an embodiment of harmonics management inan embodiment of an electrical distribution grid edge energy manager androuter device.

FIG. 27 is a flow chart of an embodiment of a cold-start protocol.

FIG. 28 shows an example of a micro-grid.

FIG. 29 is a flow chart of an embodiment of a grid formation protocol.

FIG. 30 shows a flow chart of an embodiment of a master device and slavedevice negotiation protocol.

FIG. 31 illustrates a flow chart for an embodiment of a micro-gridoperation protocol.

FIG. 32 shows an example of a micro-grid.

FIG. 33 illustrates an example of load negotiation in a micro-grid.

DETAILED DESCRIPTION

The following paragraphs describe various embodiments and features of anelectrical distribution grid edge energy manager and router device,generally referred to as the GER device. It should be understood thatnumerous embodiments of the GER device are described herein, and thus aGER device may incorporate any number of the features described below.Likewise, the embodiments of methods for managing and routing electricaldistribution described below may use different embodiments of a GERdevice.

Embodiments of the GER device may serve as an energy manager and routerat or near the edge of an electrical distribution grid. Disclosed hereinare embodiments of a GER device that may be used as a scalable energymanagement platform solution for one or more end customers in anelectrical distribution network. It should be understood that the “endcustomer” referred to herein is generally the user of electrical powerprovided by an electrical distribution network, such as the tenants of asingle family dwelling, institution, industrial location, or officebuilding, as examples. GER devices described herein may be owned and/oroperated by a utility provider (e.g., power company), and serve as acustomer-centered platform to manage energy provision and usage. Itshould be understood that alternative ownership and operationarrangements are possible.

The GER devices described herein may provide a platform to add one ormore features, described below, to a distribution transformer. GERdevices also provide additional features and benefits to both theutility company and end customer, in particular by leveraging the valueof the installation position of the distribution transformer (e.g., on apole or a pad close in proximity to the consumer's premises).Additionally, GER devices may serve as a platform for providing otherfeatures, such as, for example, communications services, local andremote management, and intelligence to components of the electricaldistribution grid.

While embodiments of the device may be used in conjunction with adistribution transformer, some embodiments of the device, discussedbelow, also include the functionality of the existing distributiontransformer (e.g., voltage step down to the voltage level used by aconsumer), and therefore can entirely replace the distributiontransformer.

A GER device may be a self-contained unit, and may be located downstreamof an energy source, such as a distribution transformer, and upstream ofan energy consumer's connection to the energy distribution grid, such asa consumer's service breaker panel. Embodiments of the GER device mayprovide energy management and routing services (among other features andservices) to one or more customers. Embodiments of the GER device may beconfigured for one or more mounting locations, such as, for example,mechanical mounting to a power line or utility pole, a ground-based padmounting, or attached to the customer premise. Embodiments of the GERdevice may be thermally stable and thermally managed through variousmechanisms, including but not limited to convection, heat pipes,optional forced air and thermoelectric coolers, as examples. Embodimentsof the GER device may include a modular multi-stage power processingcircuit that can be scaled to multiple power levels based on applicationrequirements. Embodiments of the GER device may include a computingsystem, consisting of one or more microprocessor(s) and enablingembedded software for control/status, self-management, micro gridmanagement and communications.

Embodiments of the GER device may include one or more physical layercommunications devices, including but not limited to: Wi-Fi, Wi-Max,cellular, and power-line-carrier. Some embodiments may includenon-volatile storage. Some embodiments may include a rechargeablebattery backup. The backup may be, for example, power-over-Ethernet(PoE), on device photovoltaic (PV) systems, a high-voltage (HV)inductive coil, among other conventional rechargeable power supplies.The battery backup may provide for, as examples, continued internaloperations (such as communications) during power outages, and initialstart-up when attached to a high voltage feeder. Embodiments of the GERdevice may include a GPS location service. Embodiments of the GER devicemay include one or more user interfaces (UI). The UI may be hardwired tothe device, integral to the device, or linked to the device. Forinstance, the UI may be linked to a GER device by a local RF link, acustomer premise link, and a utility central office link. A bypasscapable capability upon device fault or command. Features of the GERdevice, such as those described above and below, may be added to the GERdevice in a modular fashion. Modules may include hardware and/orsoftware.

Embodiments of the GER device may include one or more functional unitsmounted onto a main heat sink. In some embodiments, the heat sink andmounted functional units may be enclosed in an outer enclosure, and theouter enclosure may be configured for (i) pole mounting, such as on anelectrical line pole, (ii) mounting on a pad mount, or (iii) mounting onan end consumer's premise.

Mounting of equipment on a utility pole, a utility pad, or at thecustomer premises presents very different mechanical challenges,especially when various power levels are considered. Generally, meetingsuch challenges require multiple and independent mechanical designs orconfigurations. However, in some embodiments of the GER device, thesemounting challenges are met through strategically mounting of some orall of the functional components (including, for example, power stageswitches, a main controller, an application controller, and sensors) onthe heat sink, and then subsequently mounting the heat sink inside acustomized outer enclosure tailored to the specific mountingrequirements of a particular installation. In such embodiments, thefunctional switching components may be placed within a module which istransferrable across multiple application environments. The commonfunctional unit may be configured to reside in a multitude of externalenclosures and a number of mounting options. Additionally, using acommon functional unit reduces manufacturing and inventory costs.

FIG. 1 illustrates an embodiment of an electrical distribution grid edgeenergy manager and router device 1. In this embodiment, the GER device 1includes heat sink 2, a power stage switching and sensor layer 3, acontroller and application processor(s) layer 4, and one or more DCcapacitors 5. It should be understood that more than one layer may beused for various sub-components. For example, switching circuits andsensors may be on more than one layer and may be on separate layers. Itshould also be understood that sub-components may be one the same ordifferent layers. For example, switching circuits and controllerprocessors may be on the same layer. One or more layers may be modular,such that a layer may be removed from GER device 1 and replaced with adifferent layer, such as an upgraded layer or a layer providing one ormore additional and/or different features.

GER device 1 may be inserted into the distribution grid in severallocations. For example, GER device 1 may be attached directly to adistribution transformer, mounted on a power line pole or similarstructure, attached to a ground-based mounting pad, or attached to aconsumer's location (e.g., a consumer's premise). GER device 1 may beconfigured for one or more mounting options. For example, embodiments ofthe GER device may feature a common heat sink 2 and/or layers andcomponents for use with one or more mounting configurations. The commonheat sink 2 and/or layers and components may be enclosed in apole-mountable and/or a pad-mountable outer enclosure. The variouscomponents, including switching components for power processing, may belocated on one or more transferrable modules for multiple applicationenvironments.

FIG. 2 illustrates a pole-mounted embodiment of an electricaldistribution grid edge energy manager and router device. In thisembodiment, GER device 21 includes an external heat sink 22, and ismounted on utility pole 27. Distribution transformer 25 receives powerfrom high voltage input 26 from an electrical grid (not shown), andoutputs power to the GER device 21 primary input 23. GER device 21outputs power from secondary 24 to supply line 28, which provides powerto an end consumer (not shown).

In some embodiments of pole-mounted GER devices, the GER device 21 maybe located below the distribution transformer 25, and offset at about 90degrees on the pole 27 relative to the distribution transformer 25. FIG.2 demonstrates such a configuration. (One of ordinary skill in the artshould appreciate that the components shown in FIG. 2, and many otherfigures appended hereto, are not shown to scale.) The offset aids withcable dressing from the secondary of the distribution transformer 25,through the device 21, and ultimately to the end consumer through supplyline 28. Efficient cable arrangements as shown in FIG. 2 providenumerous benefits. For example, such arrangements allow for quicker andsafer installation, easy bypass of the GER device 21 if necessary, lossreduction between units, and require little—if any—changes to theexisting transformer 25. The arrangements also simplify retrofitinstallation. Thus, mounting a GER device in close proximity to thedistribution transformer minimizes disturbance to the existing wiring,minimizes electrical losses, and enables simplified mechanical bypassand device removal when necessary. In some embodiments, a GER device mayattach directly to a distribution transformer. In some embodiments, theouter enclosure of a GER device may be configured for convenientattachment to a distribution transformer, such as, for example, byhaving similar geometries and simple attachment mechanisms.

Embodiments of the GER device may incorporate multi-use mountingbrackets configured for connecting the device to a pole, such as, forexample, by strapping or bolting. Embodiments of the GER device may beconfigured for use with a multitude of pole materials and polediameters. FIG. 3 shows a schematic of an embodiment of a bracket forpole mounting embodiments from (a) the front, (b) the side, and (c) thetop of the embodiment. Although the following description includesdimensions for an embodiment of the bracket shown in FIG. 3, it shouldbe appreciated that a wide range of brackets may be used for mounting aGER device, and a bracket may be configured as needed.

In the embodiment shown in FIG. 3, bracket 31 allows the device (notshown) to be mounted on a pole via a strapping method. Strapping slots30, which may be offset from a side or top surface by 30 a, about 1-4inches, provide for use of straps to attach the bracket 31 to a pole.Viewed from the front, bracket 31 may have an I-shape. In someembodiments, the width of top 32 a and bottom 32 b of bracket 31 may beabout 20 inches, the height 32 c may be about 24 inches. In someembodiments, sides 35 and 39 may be about 7 inches, and indented surface36 and 38 may be about 5 inches. One of ordinary skill in the art shouldappreciate that bracket 31 may feature different dimensions as needed.The embodiment in FIG. 3 uses a strapping method to connect the bracket31 to a pole (not shown), but other methods for connecting bracket 31 toa pole may be used. Generally, a strapping method provides flexibilityfor adjusting to pole diameter variations, and accommodates polematerials not well-suited for drilling and bolting. Bracket 31 mayinclude attachment arms 34 that may be bent by an angle along a longaxis of a pole to improve the mounting of bracket 31 to a pole. As seenin the top view, mounting arms 34 may provide contact area along theouter surface of the cylindrical pole. A mounting arm may be bent by anangle according to the diameter of the pole and width of the bracket.For example, in the embodiment shown in FIG. 3, mounting arms 34 arebent by about 110 degrees relative to the rear surface of the bracket31. By altering the angle of the attachment arms 34, a large range ofpole diameters can be accommodated. Straps may also include strappingholes for providing other mechanisms to connect a bracket to a pole,such as, for example, bolt attachment on poles. One of ordinary skill inthe art should appreciate that the bracket may connect the GER device toa pole through another technique, such as bolting.

Embodiments of the GER device may be mounted on existing pads. FIGS. 4and 5 illustrate pad-mounted embodiments of an electrical distributiongrid edge energy manager and router device. In the embodiment shown inFIG. 4, GER device 41 is mounted on pad 44 supporting transformer 43.Some embodiments may require a pad extension 45, should the pad 44supporting the transformer 43 not provide sufficient mounting surfacefor GER device 41 and heat sink 42. Some embodiments may further includea hood that covers all or a portion of any exposed surfaces of the heatsink 42. For example, a hood may be a thin box-like structure havingvent holes that allow for heat exchange. Mounting a GER device 41 on apad may require more surface area than would normally be provided by theexisting pad 44. In such scenarios, pad mounting may be achieved by theaddition of an extended external enclosure sitting partially orcompletely on a pad-extension 45 thus adding the extra area. The commonfunctional unit described above may be enclosed in the outer enclosuremounted on the pad extension.

In some embodiments, cabling for standard pad mounted transformersenters and leaves from a space below the pad cut into the ground. Whenan additional pad is placed next to the existing pad, the pit below theexisting pad may be further dug out to increase the volume of cablemanagement space below the whole transformer and device. Primary cablesenter as before and are connected to the primary input of thedistribution transformer. Cables from the secondary of the distributiontransformer that previously exited the pit to attach to the load may beattached to the secondary of the GER device. The secondary of thedistribution transformer is attached to the primary of the GER device,such as a multiport connection bar, via a short cable assembly that maybe housed in the pit or trench. For example, in the embodiment shown inFIG. 5, GER device 51 is mounted on pad extension 55, and cables 55 exittransformer 53 under pad 54, traverse through a pit 59, and enter device51.

Under certain application scenarios the device may be mounted at thecustomer premises. FIG. 6 shows an embodiment of an electricaldistribution grid edge energy manager and router device mounted on apower consumer's premises.

The GER device 61 in FIG. 6 is attached to the customer premises 62,preferably close to the location of the metering unit 67 to simplify andreduce the cost of installation and connection. The GER device 61 mayinclude a communications link 66 to the customer premises managementsystem 65, such as, for example, an RF link or wired link. The utilitysupplied line 63 attaches to the GER device 61, through physicalcabling, and preferably before connecting to the power grid withinpremises 62. The GER device 61 may include one or more onboard meters68, as described elsewhere herein, or the device may integrate thefunctionality of an existing meter 67. Some premises 62 may includepower generation devices such as photovoltaic cells 64 a and battery orother energy storage device 64 b. Some premises 62 may includeadditional power charging supply lines, such as electrical vehiclecharger 69. Such devices may be attached to the GER device 61. Theattachment may be via a DC port, as described in more detail below.

This mounting option has certain advantages in terms of ease ofinstallation, added bypass capability, easier tie in to customer ownedrenewables, and home automation and use of existing AMI connections, toname a few. Premises mounting may be achieved in a number of manners,including, for example, a standard pad mount option on the side of thecustomer premises 62 of a wall mounted external enclosure. In anymounting option, a common functional unit may be used within the GERdevice 61.

The mounting versatility of embodiments of the GER device 61 allow for acentrally located junction point on the consumer's premise 62 fornumerous features and services described herein, including, for example,metering, power parameter control, DC-connectivity, and/or homeautomation control, and aggregation. Mounting of a utility-controlledapparatus on the consumer's premises 62 permits easy installation,integration, and maintenance, which may include internal meteringfunctions.

Advanced Metering Infrastructure (AMI) is likely to be deployedthroughout large portions of most electrical distribution gridsworldwide. The amount of data generated and communications bandwidthconsumed is likely to become an important issue for electric utilities.FIG. 7 illustrates an embodiment of a GER device 71 integrating AMIfeatures for a plurality of power consumers, Customers 1-4.

Metering data may be collected from individual consumer meters 75 by GERdevice 71, which may then process the metering data and then transmitthe data 76 (processed or unprocessed) to centralized utility facilities77, such as for billing purposes, for example. The GER device 71 may usea local communications link 74 to communicate with one or more consumermeters 75. As more components within the distribution grid becomeintelligent components, more communications traffic results, and a morecomplex and heavily utilized communications infrastructure is required.The GER device 71 may provide the ability to integrate AMI features forone or more consumers, and may locally aggregate data from multiple AMImeters 75. Integration of the AMI function 73, such as for a total loadmeter on the GER device 71, may reduce capital costs, particularly wherethe common functional units include the required metering. Additionally,the device installation location may reduce the potential for tamperingdue to the reduced access. Furthermore, communications requirements forthe consumer AMI meters 75 may be integrated with onboard GER device 71communications systems, thus reducing general traffic overhead or thenumber of specific communications links required. Aggregation of severallocal streams of AMI traffic may also significantly reduce AMI trafficoverheads and management needs, which may become valuable as datatraffic volume proliferates over time.

Some embodiments of the GER device 71 may include onboard non-volatilestorage 72. During times of communications outage, AMI data can bestored within the non-volatile storage 72 for later processing and/ortransmission. Local processing of meter data for power management,demand management, and other electric utility purposes, are among theadvantages of including an onboard AMI meter 73 in a GER device 71.Decentralized storage of metering data through various integrated datastorage methods may be included in embodiments of a GER device 71.Strategic physical installation and onboard encryption methods may beused to reduce the risk of AMI tampering.

Voltage, current, and power sensing are also features that may beincluded in embodiments of the GER device. Increasingly intelligent,efficient, and reliable distribution grids require an increased numberof sensing points where a utility acquires knowledge of voltage, currentand power quality. Increasing the number of sensing points addsvisibility to the utility, which in turn allows for improved decisionsconcerning dynamic distribution grid management and faster responses tofaults.

FIG. 8 illustrates an embodiment of an electrical distribution grid edgeenergy manager and router device 81 providing virtual PQM 83 and virtualAMI meter 82 services. Embodiments of the GER device 81 may sense andprocess data including voltage, current, power quality, and device load,for use in various applications, such as decision making and variousanalytics. The GER device 81 may receive data from one or more consumermeters 85, through a local communications link 84. Embodiments of theGER device 81 may contain voltage and current sensors at one, more thanone, or all external electrical connection terminals. Numerous sensingpoints allow the GER device 81 to perform several functions, including,for example, voltage regulation and VAR injection (Power FactorCorrection) as described below. The voltage, current, frequency andpower data sensed by the GER device 81 can also be used to provide othercustomer and utility services other than the management of these powerprocessing functions.

Embodiments of a GER device 81 including such internal power sensingprovides a virtual Power Quality Meter (PQM) at the device's installpoint. The provision of a separate PQM would normally require utilitypersonnel visiting the installation location and incurring allassociated costs. This can become extremely expensive. In embodimentsfeaturing a virtual PQM 83, load and PQM data may be reported to theutility for use in demand response programs and coordinated withcustomer-installed home management systems. Through loadcharacterization data (historical load power draws correlated to time ofthe day), the utility is able to more easily and efficientlydetect/manage outages.

When mounted on the pole or the pad and with an internal virtual AMImeter 82 in co-operation with an existing AMI meter 75 attached to oneor more customer loads that the GER device 81 is supplying (Customer, 1,2, 3, 4), the GER device 81 can conduct analysis between internal dataand that data which is provided from the external meter 75 to easilyidentify non-technical losses between a distribution transformer andcustomer premises. These features permit various protocols for detectingsuspicious or problematic events. For example, the following scenariosmay be used to determine when a GER device will flag and report an issueto the utility's central office:

Case1: NORMALVirtual AMI Meter=Customer 1 Meter+Customer 2 Meter+Customer 1Meter+Customer 4 Meter

Case2: THEFTVirtual AMI Meter>Customer 1 Meter+Customer 2 Meter+Customer 1Meter+Customer 4 Meter

Case3: UNAUTHORIZED GENERATION OR FAULTVirtual AMI Meter<Customer 1 Meter+Customer 2 Meter+Customer 1Meter+Customer 4 Meter

Thus, embodiments of the GER device 81 may include virtual PQM meters83, thereby allowing PQM capabilities at install points. Historically,PQM capabilities are achieved only through onsite utility personnel anda specialized externally-connected PQ Meter. Embodiments of the GERdevice 81 may also permit increased resolution of load and associateddemand through remotely available characterization data. Algorithms maybe used, independently or in conjunction with meter(s) or a substation,to effectively identify and communicate non-technical losses within adistribution network.

The communications infrastructure used to deliver data betweendistribution grid assets is an important element of a reliable andefficient distribution grid. A primary issue is the communicationsbandwidth and amount of data provided over a set period of time.Embodiments of the GER device may contain a physical layer providing oneor more physical layer communications capabilities. In some embodiments,the physical layer may be flexible and agnostic with respect to theevolving distribution grid communications infrastructure, such thatcommunications capabilities may be replaced, added, and/or updated asthe communications infrastructure continues to evolve.

FIG. 9 shows demonstrative communication features for an embodiment ofan electrical distribution grid edge energy manager and router device91. Embodiments of the GER device 91 may incorporate a plethora ofcommunications capabilities. Communications capabilities 92 may beprovided in a physical layer, such that capabilities may be replaced,added, and/or updated. A GER device 91 may be capable of communicationwith not only a central distribution grid management entity 94, such asa utility service provider, but also with a number of other machines andentities, including as examples only, (1) other GER devices 93, such asslave GER devices in a micro-grid as described below; (2) one or morepower supply sub-stations 95; (3) remote terminal units 96 for physicalcommunications bridging; (4) a consumer/customer load management system98; (5) an AMI network 97; and (6) various sensors on other devices,such as local non-intelligent grid assets 99.

This local communications ability is useful in relation to forming andoperating micro-grids of more than one GER device, as described below.Additionally, this local communications ability permits the uniquerouting of communications around faults as described below. Should a GERdevice or other local grid asset be incapable of reaching a centralizedmanagement entity 94, for example, the local communications links 92 mayallow communication via another GER device 91 that can reach thatcentral entity 94 via, for instance, internal routing protocols withinthe micro-grid application software within a GER device. Furthermore,embodiments of the GER device also provide encrypted communications.Encrypted communications may be on a unit by unit basis, rather thanusing one encryption key for the whole network. Encryption and accesscontrol may be changed on a rotating schedule scheme, and may beimplemented at the local level rather than network wide.

As with AMI data, other local grid assets, such as assets that providesensing data, can use these local communications links 92 to enable oneor more GER device 91 to aggregate select data, conduct localizedprocessing and/or compression, and send the results to a centralmanagement agent 94 or other destination for subsequent use orprocessing.

The ability to provide an agnostic nature in the GER device 91, withrespect to physical layer communications 92, provides for wide rangingand higher levels of co-operation between grid assets. Further, thesecapabilities offer a communications interface that may agnostic as to aservice provider. Embodiments of the GER device may also include asoftware layer configured to communicate with one or more gridcomponents and locations. Further, in micro-grid scenarios, the uniquerouting of communications internally to the micro-grid applicationsoftware may increase the likelihood of critical messages from other GERdevices 93 reaching the substation 95 or central office during an outagescenario. Local communications links 92 may also be utilized fortransmitting data stored within, received by, and/or sensed by a GERdevice.

At times of peak load or when generation capabilities are constrained,it may be beneficial for a distribution grid to employ methods to reducethe end user load in an efficient and cooperative fashion, thus avoiding“brown-outs” or eventual outages.

Embodiments of the GER device described herein present an idealdemarcation point for a load management scheme. A load management schememay be implemented at the customer level, as opposed to the historicaldistribution feeder level. The installation point of the GER devicepermits cooperation between the GER device and one or more customer loadmanagement apparatus, and may also link to any associated consumermanagement system, and a utilization of the prescribed methods for aload management scheme.

Some embodiments may use closed-loop feedback. The GER device may begiven continual knowledge of the consumer load and can essentially“negotiate” with the consumer, even on a dynamic basis, regarding powerrequirements. One of ordinary skill should appreciate that variouscombinations of utility controlled load reduction steps and customer“veto” options may be included in a load management scheme. Thisversatility allows a highly flexible and extensive range of load controlschemes. The one-to-one relationship between load and controller allowsa utility to limit and/or control brown out (or outage control), and thebrown out may be limited to a selected set of consumers.

FIG. 10 is a flow chart for one embodiment of a grid event managementmethod. The algorithm shown in FIG. 10 may be implemented within a GERdevice. Upon command or detection of a “Grid Event” S1001, the GERdevice communicates load requirements to the consumer's energymanagement system S1002. The load requirements may be based onpre-loaded or newly commanded parameters from a utility centralmanagement agent, for the specific grid event. In some embodiments, theconsumer system may be given a veto S1002, and load reduction may bebased on a requested reduction. At S1003, if the requested reduction issuccessful, then the GER device may end negotiation and await theclearing of the grid event S1008. If the initial request S1003 is notsuccessful, then the GER device may direct the consumer to reduceconsumption without any veto/negotiation option S1004. If S1004 issuccessful, then at S10005 the system may end negotiation and await theclearing of the grid event S1008. If not successful at S1004, then theGER device may cut power to the consumer load S1007. Cutting power S1007may be preceded by a warning to the consumer S1006. The GER device thenawaits the clearing of the grid event S1008. Upon clearing of the gridevent the GER device may communicate S 1009 data, such as withdrawal ofload restrictions and other updated information, to a central managementagent of master in a micro-grid S1009.

In the case of a grid event whereby a GER device loses primary power,and also runs out of any backup power, it may be desirable for the GERdevice to keep certain essential and/or pre-elected processing andcommunications functions operational in the GER device, in lieu ofshutting down completely. The close physical proximity andcommunications link between the GER device and the consumer homemanagement system provides an optional power linkage. In the optionalpower linkage, embodiments of the GER device may use power techniques todraw power from the consumer, such as Power over Ethernet (PoE), topower one or more components of the GER Device.

Thus, embodiments of the GER device may serve as an intelligentintersection for either or both a utility controlled or customer-utilitynegotiated load control. Embodiments of the GER device may include analgorithm to implement load negotiation. Embodiments of the GER devicemay incorporate a layered approach to load negotiation, which as shownin FIG. 10 may include a consumer veto option at a first negotiationstage, followed by a rejection of the veto at a later negotiation stage,followed then by individual and finite consumer power modifications toenable a more granular consumer reaction to overall grid management.Embodiments of the GER device may be capable of using any poweravailable in the consumer premises, such as generator, non-grid tiedbatteries, etc. The consumer-supplied power may be delivered via a Powerover Ethernet (PoE) communications wireline to keep essential processingand communications functions operational.

The increasing complexity of distribution grid assets is expected tocause a rise in operational and maintenance costs. It will be valuablefor intelligent devices and components of the distribution grid toinclude systems and methods that reduce or minimize operation andmaintenance costs. Embodiments of the GER device may incorporatedevices, systems and methods for reducing and/or minimizing operationand maintenance costs. For example, embodiments of the GER device may beconfigured to follow one or more algorithms that result in operation andmaintenance efficiencies. One example is internal status monitoring.Embodiments of the GER device may be configured to follow one or morealgorithms for monitoring internal status of the GER device.

FIG. 11 is a flow chart showing an embodiment of an internal statusmonitoring method. Embodiments of the GER device may include one or moreinternal status and/or performance sensors. Those sensors may be used inconnection with an internal status monitoring algorithm such as FIG. 11shows. At the start of the algorithm S1101, a GER device may initiate ininternal status check. The GER device may read all or a subset ofinternal status parameters from one or more sensors at S1102. Internalstatus and performance sensors may allow regular and commandedself-testing and sensing in some embodiments. The sensor results may bestored in a local database S1103, and in some embodiments may betransmitted to a central management agent and/or a performance historydatabase S1103 a. The performance history database may reside on the GERdevice, on another GER device, such as one involved in a micro-grid,and/or on another component of a distribution grid. The sensor resultsmay be processed locally S1104, such as comparing the sensor results topredetermined or calculated expected values or ranges. In the embodimentshown in FIG. 11, the GER device may compare the sensed data todetermine whether an indication of faulty operation is present S1105.The local processing S1104 may also perform various analyses on thedata. For example, at S1104, the GER device may look for trends insub-system reliability, which may be used to provide predictions forfuture failure, as an example. Such data analysis may be used forindications of faulty operation S1106. If faulty operation is indicated,the GER device may take appropriate action, such as bypassing, shuttingdown a system, and/or de-rating the system. S1108. Similarly, inembodiments monitoring for future failure, if future faulty operation isindicated, the GER device may take appropriate action, such asbypassing, shutting down a system, and/or de-rating the system. S1109.One of ordinary skill in the art should appreciate that a number ofappropriate actions may be included as responses to indications faultyoperation, depending on the indications and nature of the faultyoperation. The GER device may then report any combination of the senseddata, indications, and actions taken, to a management agent or anotherGER device in a micro-grid S1107. In the embodiment shown in FIG. 11,the algorithm may then repeat S1110. However, in other embodiments, theinternal status check may commence at regular or irregular intervals, oron other terms as desired.

The ability to include extensive internal monitoring capabilities in aGER device aids in the automatic calibration of various sensors in thegrid system and the GER device, thus maintaining accuracy of sensorreadings without the need for frequent calibration by utility personnelor other means. Calibration may be performed by a GER device byincluding accurate voltage references in local memory. Further, thecalibration process may be performed by an onboard processor on aregular or irregular basis, or on other terms as desired.

It should be apparent that embodiments of the GER device may beconfigured for intelligent self-testing of a grid asset, and may providenotification of failure and estimated future failure. Embodiments of theGER device may follow one or more algorithms for closed-loopself-testing and sensing. The results of these algorithms may be usedfor compiling and delivering a “wellness” report to the utility or othermonitoring authority. Internal monitoring capabilities may be linked tothe automatic calibration of onboard voltage and current sensors. Also,calibration of onboard sensors may be achieved through voltagereferences stored in a GER device.

Distribution transformers may serve one end customer or multiple endcustomers. Embodiments of the GER device described herein may be usedwith one or more end customers or consumers. Interacting with aplurality of consumers raises challenges when using a one-to-one mappingarchitecture for customer-specific features. Typically, the voltagelevel supplied to each consumer from a single GER device will besimilar, and a one-to-one communication link between the GER device andeach consumer can be maintained. However, the current, or load, beingdrawn from each consumer though a GER device may vary at any givenmoment.

Embodiments of the GER device may be configured for measuring thecurrent or load delivering to each of a plurality of consumers connectedto a single GER device. FIG. 12 illustrates an embodiment of anelectrical distribution grid edge energy manager and router devicemeasuring current drop for a plurality of power consumers. Embodimentsof the GER device 1201 may monitor consumer-specific currents on eachsupply line 1204 from the GER device 1201 to a consumer. A supply line1204 may connect to an outgoing secondary connection terminal 1206 of aGER device 1201. The GER device 1201 may feature a plurality ofconnection points 1202 for current sense cables 1203 that are connectedto the power delivery cable 1204 a, 1204 b, 1204 c going to a single endconsumer (Customer 1, Customer 2, and Customer 3, respectively). Currentsense cables may be connected to a power delivery cable 1205 in a numberof ways, such as, for example only, cable clamps 1205. A sense cable1203 may be used when a single GER device 1201 serves more than oneconsumer, providing customer-specific data in addition to the GERdevice's internal current sensing. When a GER device 1201 is supplyingpower to more than one end consumer, the internal current sensingrepresents the total load of all consumers, and each sense cable 1203indicates an individual customer's load. Monitoring an individualconsumer's load supports the advanced metering and load negotiationfeatures described elsewhere herein. The ability to monitor eachconsumer's load may be particularly useful with respect to the GERdevice's overall load control, because embodiments of the GER device maymanage overall device load control at an aggregate level for allconsumers connected to a single GER device.

Renewable energy generation is increasing dramatically and itsintegration into the distribution grid presents several challenges forprior distribution grids. Inverters are historically used to couple theDC voltage generated to the AC distribution voltage. However, invertersare expensive and have short lifetimes, and also negatively affect thegrid power quality. Utility knowledge and control of grid-tiedconsumer-owned DC generation sources is desirable for the utilities.Utility owned DC generation resources that are located within consumerpremises also present several new business models to the utility.

Embodiments of the GER device may include a bi-directional DC connectionport for receiving power from a DC generation source. FIG. 13 shows anelectrical diagram for an embodiment of a bi-directional DC connectionport 1301 included in an embodiment of an electrical distribution gridedge energy manager and router device. The port 1301 in this embodimentincorporates isolation switches 1307 a and 1307 b to connect anddisconnect the DC source 1305 as required, a DC to DC converter 1303 toallow flexibility in terms of attached DC voltage, voltage (A)V and (E)Vsensors, and current sensors (C)(I) sensing for accurate control andintegration into GER device operation. Other embodiments may featuremore or fewer sensors, and the precise location of the sensors on thecircuit may vary depending on the design and architecture of thecircuit. Power sourced is controlled via an internal shared 400V bus1304 within the GER device. The output current of the DC to DC converter1303 for the DC port 1301 may be controlled via its voltage, to allow aset amount of current to flow from the output to the DC bus 1304. Insuch embodiments, if its voltage is pushed higher than the 400V DC bus1304, then current may flow to the bus 1304 in proportion to thedifference.

In embodiments of the GER device a bi-directional DC connection port,the port may include voltage sensing of the GER device and source/loadside (A)V and (E)V. Embodiments may include current sensing in bothpoles (C)I. Embodiments may include Double Pole Single Throw (DPST)Switch capability on both sides. Some embodiments include a bridgerectifier function 1302 that may provide polarity protection.Embodiments may include a bi-directional DC/DC converter allowingcurrent injection in both directions under control. Embodiments may alsointegrate power from consumer resources at a DC voltage, therebynegating harmonics that may have been otherwise introduced via a directgrid attachment.

Thus, embodiments of the GER device may provide flexibly, controlled,and safe attachment of DC sources and sinks for integration into the ACsupply to the consumer. An internal DC bus may be used as a referencefor DC input and output. Embodiments may include closed loop control ofeach individual DC source via voltage control and current sensing toproportional load between sources. A multitude of interlocking isolationswitches may be included in some embodiments to control the direction ofpower flow. In such manners, inclusion of a DC-DC converter may negateharmonics that would have otherwise been introduced on the grid as aresult of Device attachment.

Integration of energy storage, including but not limited to batteries,capacitors, flywheels and fuel cells, into a distribution grid mayprovide several benefits. Knowledge and control of these resources iscentral to a successful integration. FIG. 14 illustrates the use of anembodiment of a bi-directional DC connection port with a power storagedevice.

In the embodiment shown in FIG. 14, GER device 1401 includes a DC port1405 that is bi-directional 1407 and 1408, and may be used for attachinga power storage device 1402 to the GER device 1401. Generally, abi-directional DC port may include an electrical connector having theability to flow electrons in two directions, e.g., both inward andoutward of the port. This may include, but is not required to include,additional connection pins as compared to a traditional unidirectionalconnector. The GER device 1401 receives line power 1403 and providesload power 1404 to a consumer (not shown). As described, control andmagnitude of energy inflow or outflow of the DC port 1405 may bevoltage-controlled as related to the internal 400V DC bus. Attachedpower storage devices 1402 may connect at DC power link 1406, and insome embodiments of the GER device may be supported at voltages as lowas 12 VDC, with internal bus adjustability typically ranging between 380VDC and 420 VDC. A fully controlled bi-directional DC port 1405synchronized with GER device 1401 knowledge of consumer loadcharacteristics allow the device to implement peak shaving and managemomentary outages.

Peak shaving occurs when peaks of demand are flattened through theaddition of stored energy as required. When applying peak shavingmethods, an increase in load 1404 would normally affect the line power1403, thus placing a generation burden on the utility. Embodiments ofthe GER device may monitor the load increase, and add power from thepower storage device 1402 connected to DC power link 1406, to meet thetemporary increase in load demand.

Momentary ride-through occurs when short duration outages aretransparent to the consumer through use of the stored energy systems.When applying ride-through methods, the main AC power may be absent fora short period of time, i.e., line power 1403 may be 0. The normalresult would be a loss of all power to the consumer. However, inembodiments of the GER device configured to perform momentaryride-through methods, the GER device 1401 may sense the line power 1403in real time, and adds DC power 1407 from power storage device 1402 tomeet the temporary load 1404 requirement. The momentary outage would betransparent to the consumer up, assuming the power storage device 1402was capable of supplying the required load. In some embodiments, a GERdevice may be configured for connection to more than one power storagedevice 1402. Ride-through capabilities may be coupled with one or moreload negotiation algorithms as described above, lowering the loadrequirement 1404 and increasing the time that outages can be stoppedfrom affecting the consumer load 1404.

The size of the storage may be approximately calculated by:Time (h)=Battery Capacity (Ah)×(Battery Voltage (V)/(Load (W)×1/PowerFactor))

Embodiments of the GER device may be configured to perform one or moremethods to sense load demands and/or generation instability, andseamlessly compensate either through a connected source of energystorage. Embodiments of the GER device may include one or more DCbi-directional ports to connect and integrate energy storage capability.As described above, embodiments of the GER device may be configured toperform one or more load negotiation algorithms to decrease loadrequirement in certain instances.

Embodiments of the GER device may also be configured to provide power toone or more additional DC loads. For instance, one or more DC ports of aGER device may be used to supply energy to DC loads such as electricalvehicle chargers or other DC power supply systems.

FIG. 15 shows an embodiment of integrating DC-based loads 1508 into anembodiment of an electrical distribution grid edge energy manager androuter device 1501. In this embodiment, the GER device 1501 provides DCload management 1507 through safety protection, load sensing, andcontrol. GER Device 1501 may meter DC loads 1508 in the same or similarway as with the AC primary load. DC load 1508 may connect to DC to DCconverter and interface 1507, which is in circuit with DC stage 1502 inthe GER device 1501.

Based on the maximum load required from the DC port 1507, and the ACLoad (e.g., Load 1 and Load 2 in FIG. 15), the GER device 1501 includesmultiple levels within the central power processing stage that canaccommodate varied power levels for the DC and AC loads. The GER devicemay employ internal software algorithms to maintain knowledge andcontrol of the balance between DC power and AC power, and may therebyensure that capabilities in each area are optimized for the currentstate of operation and load.

For example, the GER device may be configured to use an algorithm formaintaining the relationship Pvr=(Pt×Pp)−Pdc, where:

-   Pvr=power to process voltage regulation-   Pt=total power rating-   Pp=percentage of power processed (dependent on power stage)-   Pdc=power added (−ve) or subtracted (+ve) from Device via the DC    port

For example, assume a Total Rated Power at 50 kW, a percentage of totalpower processed at 10%, power processed at 5 kW, and a DC Load Runningat 3 kW. A GER device using an algorithm would determine that theremaining power for voltage regulation is =5 kVA−3 kW=2 kW.

In some embodiments, the software control algorithm may continuallymaintain knowledge of the DC load 1508, and hence remaining power forthe AC voltage regulation, and may set maximum performance ratingsaccordingly. If a central power stage is upgraded to process 20% of thetotal system power, for example, then more power may available forsharing between the SDC load and AC voltage regulation.

By incorporating a DC stage 1502 and a DC-to-DC converter and interface1507, embodiments of the GER device may be configured to employ methodsto simultaneously provide power and satisfy both AC and DC load demandssimultaneously. Embodiments of the GER device may also be configured toemploy one or more algorithms to effectively balance the distribution ofpower between simultaneously connected AC and DC loads.

Embodiments of the GER device may be configured to monitor variousparameters relating to the health and operation of other localelectrical infrastructure components, including as an example adistribution transformer providing a power source to the GER device.FIG. 16 illustrates an embodiment of an electrical distribution gridedge energy manager and router device monitoring local electricalinfrastructure components.

As the GER device 1601 may be physically installed or located at theedge of a distribution grid (e.g., downstream of a power substation, ona pole or pad close to the consumer), the GER device 1601 is at an ideallocation to conduct smart monitoring services for other gridinfrastructure components, including otherwise non-intelligentco-located devices. Devices such as the distribution transformer itself1604, and other grid assets 1605 a-1605 c, such as, for example,lightning arresters, fuse cutouts, line voltage regulators, capacitorbanks, re-closers and air break switches, lack onboard intelligence andcommunications to link with a utility central a management agent.Incorporating intelligence within each of these devices 1604 and 1605a-1605 c, would be cost-prohibitive and a large industry undertaking. Analternative is to retrofit such assets to sense status (UF), and wouldbe more reasonable value proposition to utilities. This enablesutilities to monitor troublesome existing equipment through aretrofit-able solution. Embodiments of a GER device 1601 may beconfigured to collect status information and other data from such localequipment 1604 and 1605 a-1605 c. The GER device 1601 may connect tosuch other components through a number of methods, including plug-insensing cables 1606 or local RF links, for example. The GER device 1601may collect and analyze the status of local devices, and may transmitdata and/or analysis to a utility central management agent 1603, such assubstation. Through this method of local collection, processing, andcollating of data, many local devices 1604 and 1605 a-1605 c may belinked to the distribution grid more efficiently, without requiring asignificant increase in communications traffic across the grid.

In some embodiments, one or more sensors, capable of retrofit, may beattached to pre-existing, or installed, electrical equipment. Suchsensors may communicate chosen parameters to one or more GER devicesthrough any communications path, such as a physical link or radio link.Embodiments of the GER device may accommodate a variety of add-onlocalized sensory. Embodiments of the GER device may be configured toemploy internal algorithms to process and/or communicate informationfrom the sensors to utility management. Integration of local grid assetstatus data based on consumer, feeder segment or full feeder allocationmay reduce communications traffic, and offers geographically relevantsummarized status data to the utility management.

Voltage regulation is an important element of distribution gridmanagement. Conservation Voltage Reduction (CVR) is one method forvoltage regulation and management. In CVR methods, the utility reducesthe voltage at a substation, and then boosts the voltage as needed alongthe feeder circuits to ultimately to save energy. In order to implementenergy savings, a flatter voltage profile within the distributionnetwork is extremely beneficial.

FIGS. 17A-C show (a) voltage reduction from electrical losses, (b)traditional voltage regulation methodology, and (c) an embodiment ofvoltage regulation according to methods described herein.

As shown in FIG. 17A, without any voltage reduction, the load side andline side voltage reduces along the feeder as a natural result ofelectrical losses along the line 1701. Distribution transformersconnected to consumers near the substation are the same as thoseconnected at the end of the feeder, resulting in the high-voltage 1701 ato low-voltage 1701 b delta being extremely similar. They are passiveelectrical apparatus. The substation starting voltage is adjusted sothat the voltage to the consumer at the end of the feeder circuit isabove the minimum allowable level, in the US defined by ANSI C84.1.

FIG. 17B shows a traditional voltage regulation method, in which alimited number of static compensators 1704 are implemented. This is doneto allow the voltage at the substation to be lowered. At a utilitycalculated point 1703, downstream of the substation, the feeder voltageis then raised, affecting all consumers and distribution transformersdownstream. Certainly there is a notable cost of efficiency in thismethod.

FIG. 17C shows an embodiment of a voltage regulation method including aGER device. In using the voltage regulation capabilities of the GERdevice, the substation voltage can be lowered and the voltage on thesecondary, or load, side (A) is adjusted at each customer so that eachload is within voltage specification. Although the distributiontransformer output voltage may be out of specification, the Deviceprotects and dynamically corrects the voltage. As can be seen in FIG.17C, both profiles 1705 a and 1705 b are significantly lower compared tothe profiles in FIGS. 17A and 17B.

Embodiments of the GER device may provide a dynamically controllablevoltage set point that can be set from a remote location, such as theutility central management agent or a local controller in a micro-gridscenario. Using real time clock features and internal processing, theGER device may also provide a time-scheduled voltage profile, with orwithout external control. This time scheduled profile can in turn beadjusted by past load characteristics and heuristics algorithms.

In comparison to traditional voltage optimization methods, architecturesemploying embodiments of the GER device save significantly more power.The unique topology including multiple GER devices allows the feedervoltage profile to be essentially flat. This enables the next generationof conservation voltage reduction programs.

Another component of voltage management involves the increasing numberof photovoltaic installations within the feeder networks. Consumersrequesting to grid-tie such PV devices create a problem for what mayotherwise be a balanced distribution feeder. In order to back-feedunused power onto the grid, the voltage potential of the consumer mustbe higher than the output of distribution transformer. The PV creates alocation, or pocket, of higher potential (voltage), whereas there isthen no control over the PV's decision to adjust voltage to all otherconnected loads. Embodiments of the GER device may include a switchingmechanism to allow for momentary unused power to have a higher potentialso that it is effectively shared with other consumers connected to thatGER device. Furthermore, these points of fluctuation on the distributionfeeder create an unbalance at a point within the feeder and anunexpected variation in the voltage level at a point unpredictable bythe electric utility, which may cause other customers to experiencevoltage levels outside of the allowable range. Ensuring a constantvoltage to the consumer is valuable because utilities are required tokeep voltage within a range. Embodiments of a GER device may beconfigured to maintain a constant voltage to the consumer, as describedelsewhere herein.

Thus, embodiments of the GER device may actively monitor and adjustsvoltage to enable energy savings and integration of DC-based devices.Closed-loop feedback to the GER device may enable auto-correctingvoltage to a dynamically-adjustable set point, regardless of externalelectrical conditions. Voltage management circuitry including inembodiments of the GER device may be configured for adjustment from aninternal command or algorithm. Embodiments of the GER device may beconfigured to employ one or more integrated algorithms to controlvoltage management components within GER device, allowing for nearlyinstantaneous adjustment of voltage based on onboard sensor feedback.Embodiments of the GER device may be configured for use in activevoltage management of photovoltaic connection points that allows forunused power flow to be shared with other consumers connected to the GERdevice, yet not affect the distribution feeder. Similarly, embodimentsof a GER device may apply one or more voltage management schemes toprovide one or more consumers with a constant voltage. Further, a gridtopology including a number of GER devices within an electricaldistribution feeder may enable the feeder voltage profile to nearly beflat from the substation to endpoint.

Managing reactive loads is important in distribution grid management.Reactive power is generally caused by capacitive and inductiveimpedances in the consumer load. In other words, the reactive power iscaused by the current draw of a load being out of phase by some degreeto the voltage draw. It creates a reactive power component within thedistribution network that is generally not revenue bearing. Thisreactive component is also often a result of active voltage managementdevices.

FIGS. 18A and 18B show the management of reactive power loads. As shownin FIG. 18A, in typical distribution networks, the inductive load 1832creates a reactive power vector that increases apparent power that theutility must generate. This difference is characterized by the PowerFactor that is equal to the Cosine of the angle between the Apparent andReal power vectors as reflected in diagram 1801. This Power Factor isalso relevant at the line side of the distribution transformer 1831.

As shown in FIG. 18B, embodiments of the GER device 1846 may be insertedin the grid, such as at the load side circuit of the distributiontransformer 1841. In such embodiments, the reactive power may becompensated through insertion of reactive power in the oppositedirection, e.g., capacitive power to negate inductive power and theconverse if the load is capacitive. For example, if the inductive load(E) with Power Factor of 0.9 in FIG. 18B is not seen by the distributiontransformer 1841 on its load side or on the high voltage side of thedistribution transformer. A load with Power Factor of 1.0 is witnessed,hence theta is zero and Apparent Power equals Real Power (S=P) asreflected in diagram 1802.

In the embodiment shown in FIG. 18B, the GER device 1846 provides adynamically controllable reactive power set point between 0.9 and 1.0(leading or lagging) with a fixed VAR component, a controllable VARcomponent, or combination of the two. The VAR component can be set fromremote location such as the utility central management agent or a localcontroller in a micro grid scenario. Using real time clock features andinternal processing, the GER device 1846 can provide a time-scheduledreactive power profile without external control. This time scheduledprofile can in turn be fine-tuned by past load characteristics andheuristics algorithms. One of ordinary skill in the art shouldappreciate that embodiments of the GER device 1846 may inject reactivepower, which may be decoupled from voltage management through the systemarchitecture and/or managed through algorithms.

The active VAR management may, in some embodiments, be decoupled fromvoltage management. VAR management may be conducted through a fixedcomponent, controllable component, or combination of the two. Managementof VAR may occur locally or remotely, such as through a set point thatmay be defined in terms of a power factor. VAR management circuitrywithin the GER device may be adjusted by an internal command oralgorithm. Example circuits and algorithms are described in co-pendingU.S. application Ser. Nos. 14/310,963 and 14/310,987, the contents ofwhich are incorporated by reference in their entirety. An integratedalgorithm controlling VAR management components may be included inembodiments of the GER device that allows for nearly instantaneousadjustment of reactive power based on, for example, onboard sensorfeedback. Some embodiments may include a topology involving multiple GERdevices within an electrical distribution grid to enable the reactivepower component within the grid to be reduced or eliminated.

When AC devices are combined, the frequency of each component needs tobe in synchronization, as a small phase difference will result invarying power as the AC sources go in and out of phase. Lack ofsynchronization presents notable problem for combining power sources inthe utility distribution grid. Embodiments of the GER device may beconfigured to synchronize frequency from more than one power source.FIG. 19 illustrates frequency synchronization in an embodiment of anelectrical distribution grid edge energy manager and router device

As shown in FIG. 19, power sources 1902 and 1908 may be combined at theDC level or stage 1904 within a GER device 1901, such as through ashared 400V DC bus 1904. Combining AC power sources at a DC stage 1904effectively synchronizes the frequency and otherwise integratesout-of-AC phase sources. AC Source 1902 and AC Source 1908 can be at anyphase relationship, may connect to an AC-to-DC converter 1903 and 1907,respectively. Embodiments of the GER device may include a plurality ofAC-to-DC converters. Power from the plurality of AC sources 1902 and1908 may be combined at the DC stage 1904. The power exiting the GERdevice may then be re-constituted into a new AC wave of a fixedfrequency by DC-to-AC converter 1905. The use of an internal DC bus 1904within a GER device may thus be used for synchronizing various ACsources which may (or may not) be out of sync. The ability to connectmultiple out-of-sync AC devices to a GER device thus allows for theadvantageous management of the AC sources, and output power in a singleAC waveform 1906.

There are an increasing number of assets being inserted into thedistribution grid, and many of those assets may communicateindependently of other assets. Embodiments of the GER device may beconfigured for supporting or creating a communication network providingcommunication through one or more communications services. The GERdevice installation location provides for a topology as the center of anextensive communications network. When configured to combine and routecommunication, embodiments of the GER device may spare bandwidth, andsome embodiments of the GER device may provide higher bandwidths.

FIG. 20 shows an embodiment of an electrical distribution grid edgeenergy manager and router device 2001 operating as a platform forcommunication services 2003 and 2005. In this embodiment, GER device2001 is located at a utility easement, although a GER device 2001 may belocated at numerous points at the grid edge as described above.Embodiments of the GER device 2001 may provide various communicationsservices 2003 to the utility, such as by integration communicationsservices 2003 with the utility communications infrastructure 2002.Embodiments of the GER device 2001 may be configured such thatcommunications services are capable of being added, removed, and/orupdated on a physical layer, thereby providing for efficient methods ofadapting to the evolving distribution grid infrastructure. The GERdevice 2001 may also provide a platform for offering of communicationservices to one or more consumers 2004 through, for example, Wi-Fi links2005. Some embodiments may also provide a cellular microcell uCell, andsome embodiments may provide direct cable connection such as Ethernet.One of ordinary skill in the art should appreciate that a GER device mayprovide any number of available communications services. These physicaland lower layer facilities may also allow the utility to offercommunications services to consumers through direct connections such asWi-Fi and Ethernet or a shared facility such as a shared Wi-Fi accesspoint or a micro-cell for cellular communications.

One of ordinary skill in the art should appreciate that embodiments ofthe GER device may be incorporated into various grid networkcommunications topologies. For example, the topology shown in FIG. 20involves GER device 2001 as a central communications hub for one or morelocal communications services uCell and 2005, and also as acommunications access service 2003 for other utility owned equipment.Embodiments of the GER device 2001 may include an integrated andflexible communications bus providing one or more linkages with utilityowned equipment. Embodiments of the GER device 2001 may be configured touse one or more algorithms for the handling, prioritization, andprocessing of various communications signals, as one of ordinary skillin the art should appreciate.

The increased complexity of the distribution grid and assets will createunforeseen operational scenarios, making safety monitoring an importantelement of distribution grid management. Embodiments of the GER devicemay be configured to include multiple layers of safety protection andthat allow the GER device to fail safely. FIG. 21 is a flow chart of anembodiment of a multi-stage safety protocol. One of ordinary skill inthe art should appreciate that numerous safety protocols are possible,and one or more safety protocol may be included in a GER device.

In the exemplar algorithm in FIG. 21, a poll of all safety devices S2101may occur on a predetermined basis or randomized basis. The GER devicemay include one or more processors configured to read or receive datafrom internal and external sensors related to the GER device'soperation, and determine whether any parameters are outside ofpredetermined or calculated safety specifications S2102. For example,the GER device may monitor external temperature and humidity, and adjustone or more parameters based on such conditions at S2102. If one or moreparameters are determined to be outside a safety specification, then theGER device may take a predetermined action S2105, such as shutting down,bypassing, or de-rating. For over-current, over-voltage andover-temperature, for example, the GER device may employ software safetymonitoring set to a fast reaction time. If parameters are within safetyspecifications, then the GER device may determine whether any resettablefuses are blown S2103. If so, then the system may take an appropriateaction S2107, which may be a predetermine action such as bypassing,shutting down, or de-rating. In this embodiment, software resettablecircuit breakers may be set to an intermediate reaction time S2108, forexample. Next, if a one-time fuse has blown S2104, then the GER devicemay take an appropriate action S2109. Physical fuses may be set at thelongest reaction time, as a last resort for safe operation. Depending onthe scenario, the GER device may either end the safety check S2110, orreset the indicators and communicate results to the utility S2106.

Multi-layer protection, such as the algorithm shown in FIG. 21, reducesthe need for utility personnel physically servicing the GER device aftereach and every fault condition. After any layer of internal faultrestoration, the appropriate actions may be taken and the GER device maycommunicate the event to the central management agent or micro-grid GERdevice (e.g., a master GER device on the same micro-grid) S2106. In someembodiments of the algorithm, operation continues at the new level ofperformance. An internal rechargeable battery may be incorporated intosome embodiments of the GER device to ensure that internal computingresources will be able to conduct the safety algorithm will continueeven in the absence of primary power.

Embodiments of the GER device may be configured for partial or completeinternal bypass, whereby the GER device removes itself from the circuitin predetermined situations, such as if a fully safe operational stateis not possible. FIG. 22 is an electrical circuit diagram showing oneembodiment of an internal bypass in an embodiment of an electricaldistribution grid edge energy manager and router device. The basic GERdevice bypass topology as shown in FIG. 22 includes a rectifier 2205, aninverter 2206, and DC stage 2208, and a plurality of inductors andtransformers 2207 a-1 within the GER device circuitry. In the exemplarcircuit shown in FIG. 22, it can be seen that if all switching devices2207 a-2207 1 are set as open (also their default state if power isremoved from their driving circuitry) then the entire central powerprocessing stage is negated and all power flows direct from input 2202to output 2203 as a simple conductive path.

Implementation of multilayer safety protocols, such as the algorithmshown in FIG. 21, may help avoid unnecessary attention of nuisance andnon-critical faults. The integration of a rechargeable battery mayfurther ensure that safety algorithms are capable of continuousoperation, even during a grid outage. Also, circuitry allowing for aninternal bypass of power management electronics may be included in a GERdevice. Layered safety systems with intelligent sensing and recovery maybe included in embodiments of the GER device, and help to reduce theeffects of faults on grid operations and outages.

The broad range of environments in which GER devices may be employedraises the importance of internal thermal management. Generally,internal thermal management is a useful indicator of a GER device'shealth. FIG. 23 shows (A) an embodiment of a method for heat management,and (B) and (C) show an embodiment of an electrical distribution gridedge energy manager and router device using distribution lines asadditional heat sinks.

As shown in FIG. 23(A), a GER device may monitor system temperature on areal-time basis, and scan for the system temperature exceeding athreshold, such as an active cooling set point S2301. The threshold maybe a temperature at which internal active cooling mechanisms engage. Thethreshold may be variable on internal and external parameters, such asexternal temperature, weather forecasts (e.g., based on data receivedthat indicates expected temperatures and humidity), and the like. If thesystem temperature, which may be monitored by one or more onboardsensors, exceeds the threshold, then the device may engage activecooling S2302. In the embodiment of the method shown in FIG. 23(A), theGER device may also de-rate based on the system temperature S2303. Forexample, if the system temperature exceeds a second threshold, which maybe a de-rating set point, then de-rating may occur S2304. De-rating maybe in proportion to the system temperature, or may be based on otheralgorithms and/or parameters.

Embodiments of the GER device may use multiple methods to manageexcessive system temperatures. For example, active cooling may be used,such as described with respect to FIG. 23(A), to operate above a certainambient temperature. Although active cooling is historically unfavorableat utilities due to maintenance requirements, it may be a requirementwith electronic-based devices. Thus, embodiments of the GER device mayinclude an active cooling (such as, for example, a forced air) system.Such cooling systems normally do not have a negative impact onperformance when not operational, but if activated the active coolingmay reduce performance de-rating which is can be based on the standardmode of high temperature operation.

Software de-rating of performance may be based on ambient temperature.Extremes in operating temperature generally do not damage powerelectronics, but may limit the functional power range of a GER device.Through the use of internal temperature monitoring and intelligentcontrol of the power stage, such as through the exemplar method shown inFIG. 23(A), embodiments of the GER device may de-rate performanceproportionally to internal ambient temperature.

Embodiments of the GER device may also include one or more external heatsinks, such as shown in FIGS. 23(B) and (C). For example, placing one ormore power stage heat sinks 2302 on the underside of GER device 2301enclosure may reduce solar loading. As shown in (B), GER device 2301 ismounted to pole 2303. In such mountings, embodiments of the GER device2301 have several mechanical enclosure options to locate one or moreheat sinks 2302 on the lower face of the enclosure. One of ordinaryskill in the art should appreciate that heat sinks may be positioned atother locations on a GER device, including internal to the outerenclosure, and at surfaces other than the underside. Embodiments of theGER device 2301 may also use distribution lines 2306 as extended heatsinks. Embodiments of the GER device 2301 may also provide thermalroutes from the GER device 2301 and heat sink 2302 to the high voltagetransmission lines B or the ground connection 2307. Such thermal routesmay proceed along routes different than the route shown in FIG. 23(B).Connection is made via ceramic thermally conductive but electricallyisolating clamps (A). Similarly, for pad-mounted GER devices as shown inFIG. 23(C), thermal routes may proceed from heat sink 2302 to groundconnection 2309. Such options provide additional heat sinkingpossibilities that take advantage of installation location.

The pad mount enclosure shown in FIG. 23(C) also provides the optionalfor earth cooling via thermal pathways 2309 to the earth through one ormore ceramic, thermally conductive but electrically isolating clamps A.Such clamps may be place in various locations, such as beneath the pad,and provide as addition heat sinking possibilities in certaininstallation locations.

As described above, embodiments may use internal GER device temperaturemonitoring in an algorithm that intelligently controls the GER devicepower stage. Controlling the power stage may also involve de-rating GERdevice performance based on the temperature conditions. Also, placementof power stage heat sinks on the underside of pole-mounted GER devicesmay limit solar loading. Some embodiments may use distribution linesand/or ground connection cabling as a thermal dissipation routes.Pad-mounted embodiments may use earth thermal capacitor cooling methodsas an additional thermal dissipation route. Embodiments may also usethermally conductive but electrically isolating clamps.

Embodiments of the GER device may incorporate high-voltage tolow-voltage conversion functionality. Depending on the conversion size,such embodiments may eliminate the distribution transformer. FIG. 24illustrates one embodiment of an electrical distribution grid edgeenergy manager and router device 2401 incorporating a voltage conversionfunction 2402. The high-to-low voltage converter 2402 may be internal tothe GER device 2401, e.g., within the same outer enclosure or sharingone or more internal layers (e.g., circuit boards). Alternatively, thevoltage converter 2402 may be external, such that the converter 2402attaches to the GER device 2401. The voltage conversion capability 2402may therefore be included with one or more of the features describedabove, or alternatively the voltage conversion capability 2402 may beimplemented as a stand-alone capability within the distribution network.The voltage conversion capability 2402 provides for a fully solid state,single unit solution, and creates a smaller foot print for installation.Further, some embodiments of the voltage converter 2402 permitbi-directional flow of electricity. Such embodiments may advantageouslysupport applications in which consumers include those connected to asame transformer and also include one or more local power generationsources connected to the distribution grid.

The integrated high voltage to low voltage capability 2402 may bepackaged within an existing distribution transformer enclosure footprintwith a connection strategy similar to existing transformer. Thisapproach has the potential to reduce the learning curve associated withinstallers learning new installation methods.

The voltage converter functionality may magnify the heat generated by aGER device. Embodiments of the GER device may be configured for advancedcooling structures, such as the structures shown in FIG. 25. The GERdevice 2501 shown in FIG. 25 is generally cylindrical, with a hollowedcenter volume 2503 for a cooling channel 2504. For example, cool air (orother fluid) may be supplied to one end of a hollow volume 2502 a, andbe forced through the hollow volume 2503 to an exit end 2502 b of thehollow volume 2503. Other embodiments may use different geometries, andmay include more than one hollowed volume for cooling. As shown in FIG.25(C), heat generating devices 2506 may be positioned in close proximityto, and even in contact with, hollow center volume 2503. Components thatdo not generate heat 2507 may be positioned elsewhere. Adding fins andbaffling projecting into the hollow center region 2503 may also improveconvection effectiveness.

The voltage conversion functionality in some embodiments of the GERdevice may necessitate one or more methods for managing and metering thebidirectional power flow from distributed power generation devices.Historically, metering power generation devices has been completedthrough a concept referred to as “net metering,” which merely providesan estimate of power being returned to the distribution grid from alocalized generation source. In most current distribution grids, excesspower that is fed to the distribution grid from the consumers' premisesstays on the secondary side of the distribution transformer, benefittingonly homes connected to the same transformer. In some embodiments of theGER device, power from a power generation device, such as a consumer'sphotovoltaic cell or another generation device attached to the grid, maybe routed by a GER device to one or more other destinations on the grid.

Embodiments of the GER device may be coupled with a high-voltage tolow-voltage conversion function with other capabilities as describedherein. Including high-low voltage conversion in an embodiment of a GERdevice allows for the capability to bi-directionally flow power onto thedistribution grid to consumers within the distribution feeder (i.e. flowof power from the secondary, or low voltage consumer side to the primaryside, or high voltage utility distribution network side), as opposed toonly those connected to the transformer where a generation source ispresent. Embodiments of the GER device may be configured to employcircuitry and one or more integrated algorithms or methods to enable thebidirectional flow of power.

Attaching new-to-market grid assets, renewable sources and loads, andconsumer-purchased devices, all introduce undesirable harmonics into thedistribution grid. These harmonics reduce the effectiveness of powerdelivery within the grid and shorten the life of both utility-owned andconsumer equipment. Embodiments of the GER device may be configured withcircuitry to manage a range of harmonics, including minimizing GERdevice-generated harmonics and filtering and isolating harmonicsgenerated by other assets.

FIG. 26 shows a schematic for an embodiment of harmonics management inan embodiment of an electrical distribution grid edge energy manager androuter device. The embodiment 2601 shown in FIG. 26 includes a two-stagearchitecture combines a Power Factor Correction (PFC) stage 2604 andVoltage Regulation (VR) stage 2605 with an intermediate DC stage 2609,although other configurations are possible. This allows for harmonicisolation between Line side 2602 and Load side 2607. The Controller ofthe power stage 2608, which may have the ability to sense and control,may alter its control of embedded switching devices and GER behaviorbased on the sensed presence of undesirable harmonics. Filters on theline 2603 and load (input and output) side 2606 provide furtherisolation of harmonics and are sensed and controlled via the power stagecontroller.

A central DC stage 2609 may be used in a GER device to assist harmonicisolation. Embodiments of a GER device may use integrated circuitry suchas shown in FIG. 26 to minimize the resulting harmonics of utilizingpower electronics in grid-scale applications. The circuitry may alsomanage and minimize harmonics from other equipment. The combination of apower factor correction stage 2604 and a voltage regulation stage 2605with an intermediate DC stage 2609, allows for isolation between lineand load sides. The integrated capability of the controller 2608 toalter algorithms based on internally-sensed harmonics may be used inembodiments of the GER device to adjust operating parameters andminimize GER device-generated harmonics. Filters, such as line-side 2603and load-side 2606 filters, may be included in embodiments of the GERdevice and controlled by a central power stage.

Broad scale outages will likely occur in a distribution grid. Inrestoring electrical service to consumers after a broad scale outage,utilities typically restore power to consumers in a controlled,sequenced, and graduated manner. Such restoration protocols help avoidthe detrimental in-rush current effects, irregular demands on generationcapabilities, and potential damage to utility equipment. The powermarket refers to such restoration of power as a “cold start,” andhistorically cold starts have been manually controlled.

Embodiments of the GER device may be configured to operate protocols forrestoring power distribution via cold start protocols. Such protocolsmay call for resumption of power distribution to consumers in astaggered and/or sequenced manner. FIG. 27 is a flow chart of anembodiment of a cold-start protocol. One of ordinary skill in the artshould appreciate that the exemplar protocol shown in FIG. 27 is one ofnumerous methods for cold start protocols. Embodiments of a GER devicemay be configured to use one or more such protocols. Further,embodiments of the GER device may be configured to receive new, updated,and/or revised protocols, such as may be provided by an end user orutility.

In the exemplar protocol shown in FIG. 27, a GER device received acommand to restore power to consumers S2701. The command may be issuedby an end user or utility, and may come from a central management agentor, as another example, another GER device, such as a GER device in amicro-grid serving as a master device. Upon receipt of a restore commandS2702, the GER device enters procedures to restore power. For instance,the GER device may generate a random time for initiating resumption ofpower distribution S2702. By use of internal processing, timers andrandom number generation, the GER device is able to provide a randomdelay between any two set boundary numbers to restore power to aconnected consumer, after power is made present at the GER device'sinput. After the generated amount of time elapses (or at another signal)S2703, the GER device may restore power S2704 and resume normaloperation. One of ordinary skill in the art should appreciate that othermethods for sequencing cold starts may be employed.

In some embodiments, the time pause before power restoration may bepreset by another source, such as, for example, a utility or other enduser, a central management agent, or another GER device within a commonmicro-grid. In some embodiments, the cold start protocol may beconfigured for use and/or combined with cooperative load managementtechniques and protocols discussed elsewhere herein, to provide an evensmoother power restoration.

Embodiments of the GER device may include embedded intelligence, i.e.,one or more protocols, configured to enable random, deliberate,sequential, and/or timed resumption of power delivery. One or morealgorithms and/or random number generator may be used to delay powerdelivery or restoration to a set of connected consumers for the purposeof demand smoothing. Embodiments of the GER device may be configured toinhibit and control power flow to a consumer based on one or moreconditions and/or protocols, even if power is available through the GERdevice's input terminals.

The GER device installation location creates an opportunity tocomplement the traditional electric utility service of electricitydelivery and power management. Embodiments of the GER device may includeone or more of additional onboard computing capabilities,communications, and GPS services, may be used for additional purposes.Furthermore, embodiments of the GER device may include outer enclosureshaving the capability to include additional equipment. This flexibilityallows for end users such as electric utilities to diversify the scopeand features of service delivery to consumers, recoup the cost ofinstallation through partnering with third-party service providers thatmay benefit from a valuable topology, and/or defer the cost ofinstallation to a third-party service provider (to name a few examplesof possible configurations). Examples of services that may be integratedinclude, but are not limited to, cellular repeaters, weather sensing andmapping, barometric pressure sensors and/or other sensors to pinpointstorm tracking; surveillance; EMS communications; DOT and trafficcontrol. Services may be correlated with other onboard communicationscapabilities, or operated independently.

One of ordinary skill in the art should appreciate that a wide varietyof additional and, in many instances, non-traditional, electric utilityservices may be incorporated into embodiments of the GER device. Theseservices allow end users to maximize the use of the many topologies thatmay be created through installation of GER devices, within the electricutility distribution grid. Integration of additional sensorycapabilities, such as barometric pressure, sound, and video, and/orcellular hardware provides numerous options for diversifying theservices provided by embodiments of the GER device.

Embodiments of the GER device may perform power management andutility-service capabilities through various internal circuit and layercalibrations and configurations, direct commands from one or more of anend user, such as a utility, a central management agent, and amicro-grid controller or other GER device, and/or one or more internallyloaded rules and algorithms, for example. The large number of potentialinternal and attached sensor inputs allow for many of a GER device'soperational rules and algorithms to be replaced, revised, and updatedover time. Embodiments of the GER device may also employ one or morelearning or heuristic methods to modify operational rules andalgorithms. A GER device's system heuristics may use data from that GERdevice, and may use data from other GER devices (such as in amicro-grid, for example). One of ordinary skill in the art shouldappreciate that processor and data storage components in a GER devicemay include the capability to receive, track, and analyze various data,then apply one or more algorithms to enable the GER device to makeeducated decisions regarding various features and functions, such aspower management, for example. Heuristic algorithms may be monitored,controlled, and/or adjusted through a GER device control through, forexample, a central management agent or micro-grid controller.

The functionality of the GER device may be expanded in situations whenmore than one GER device is installed in a distribution grid.Embodiments of the GER device may be configured to interact with and actin cooperation with one or more other GER devices. For instance, GERdevices may communicate with each other to share information, data, etc.GER devices may also be configured to form localized micro-grids. Amicro-grid may include one or more GER devices, in communication witheach other. Micro-grids may be formed automatically, such as if morethan one GER device is within a specified distance from another GERdevice or in the same geographical region. Alternatively, micro-gridsmay be formed under command or automatically upon various externalevents.

A micro-grid may include more than one GER device, such as two or moreGER devices on the same feeder circuit. GER devices in a micro-grid maybe sequential to each other along a section of a feeder circuit. Amicro-grid may form a shared communications infrastructure, in whichmultiple PHY-layer protocols including but not limited to Wi-Fi, Wi-Max,cellular, power-line-carrier. A micro-grid may further include a commonmessaging layer, allowing device-to-device communications between GERdevices in the same micro-grid (or other arrangements of GER devices).Micro-grids may also provide or generate a unique identification schemethrough which each GER device may be identified. A GER device may bepart of one or more micro-grids.

Upon a central command, power outage or reduction in capability of thedistribution grid, preserving energy is a high priority. This can beaccomplished through to the active control of loads and available energysources. To enable this, Devices in an isolated section of a feeder withcommunication capabilities still functional will form an organized groupto optimize use of available energy sources and control of attachedload. Within the market, this group of local resources is generallyreferred to as a Micro Grid and the loss of a centralized power sourceintroduces a situation referred to as islanding.

FIG. 28 shows an example of a micro-grid 2800. Micro-grid 2800 in thisembodiment comprises a plurality of GER devices 2801 a-2801 d. As shownin this embodiment, each GER device 2801 is providing power distributionto a single customer premises 2803. The GER devices in micro-grid 2800have established communications links between each GER device, and themicro-grid 2800 established that GER device 2801 a would operate as themaster GER device in the micro-grid, and that GER devices 2801 b-d wouldoperate as slave GER devices. In this embodiment, the master GER device2801 a communicates with a central utility management entity 2802, suchthat the end user or utility may send and receive information, includingmessages, instructions, and data, to the micro-grid (or one or moreslave GER devices) through master GER device 2801 a. One of ordinaryskill in the art should appreciate that other micro-grid communicationspathways are possible. For example, in some embodiments, central utilitymanagement entity 2802 may also communicate with individual GER devices.Similarly, slave GER devices may communicate with other slave GERdevices.

Embodiments of the GER device may be configured to use algorithms that,upon the occurrence of one or more predefined grid events, the GERdevice enters into a “grid formation” mode. The GER device may then pollfor local GER devices in an attempt to form a micro-grid with other GERdevices in a common area, for example. Micro-grids may be formed amongGER devices based on more than location. For instance, a micro-grid maybe formed among GER devices with a common set of features (e.g., all GERdevices in a micro-grid include voltage management or surveillancecapabilities). As another example, a micro-grid may be formed betweenGER devices with a shared local communications link; such as Wi-Fi,ZigBee or another local RF system, a cabled network, or a virtualnetwork formed at a higher layer on a broader communications networksuch as cellular WAN. As another example, a micro-grid can be formed bytype of customer (e.g. residential, senior living center, grocerycenter, gas stations) and/or geographical area.

Micro-grid formation and operation may be accomplished through one ormore algorithms, as should be appreciated by one of ordinary skill inthe art. Alternatively, these algorithms can be combined as would beevident to one of ordinary skill in the art.

FIG. 29 is a flow chart of an embodiment of a grid formation protocol.Under the exemplar protocol, GER devices will enter Grid Formation Modeupon the occurrence of a grid formation event S2901. For example, a gridformation event may include any of the following: a command to do so bythe central management agent; losing communication with the centralmanagement agent; receiving a grid request from another GER device; etc.If a grid formation event has not occurred, then the GER device maycontinue operating in a prior setting S2902.

When a GER device is in Grid Formation Mode, it may then signal theevent to one or more other GER devices S2903, and wait for responses.Responses may indicate the state of other GER devices. In someembodiments, the GER device may continue in normal operation mode whilelistening of other GER devices. One another GER device has beenidentified, the protocol in FIG. 29 allows for the entry of a found GERdevice into or otherwise update a grid database S2906. After apredetermined amount of listening, or devices found, or other limitationS2905, the GER device may cease listening and begin another micro-gridalgorithm, such as a master/slave negotiation S2907. One of ordinaryskill in the art should appreciate that other algorithms may follow.Further, one of ordinary skill should appreciate that a GER device maycontinue in listening mode after starting another algorithm, such as amaster/slave negotiation algorithm. In some embodiments of micro-gridformation protocols, a single GER device may form a micro-grid withidentified GER devices that are also in Grid Formation Mode. In this waythe size, configuration and geographic location of a formed micro-gridcan be controlled via commands from the central management agent to eachdevice to go into Grid Formation Mode or local algorithms based onexternal conditions. In other embodiments of micro-grid formationprotocols, a GER device that has entered Grid Formation Mode mayinstruct other GER devices to enter Grid Formation Mode.

A micro-grid may include one or more GER devices identified as a masterdevice, and one or more GER devices identified as a slave device. Amaster device may be given certain responsibilities, capabilities, etc.,and/or serve as a primary point of communication for other micro-grids,a utility, or other end user, for example. A slave device may depend ona master device for one or more services or instructions, such as whento delivery power, when to cold start, etc. Numerous methods may be usedto identify master and slave devices. For example, FIG. 30 shows a flowchart of an embodiment of a master device and slave device negotiationprotocol. In the exemplar protocol shown in FIG. 30, GER devices thatcommunicate regarding forming a micro-grid may initially decide on whichGER device is master through a simple ruling based on an embedded serialnumber (A) such as highest or lowest or based on previous configurationfrom a central management agent.

As shown in FIG. 30, GER devices may enter a master/slave negotiationalgorithm S3001. In this simple protocol, the negotiation may be basedon the serial number pre-assigned to each GER device S3002. Serialnumbers of GER devices in a micro-grid may be added to a grid databaseS3003. After all GER devices have provided serial numbers S3004, thenthe highest (or lowest) serial number may determine the master deviceS3005. One of ordinary skill in the art should appreciate that othermethods of identifying the master device as possible, such as relativelocation along a feeder circuit, geographical location, onboardcommunications features, etc. Depending on the master/slave assignment,each GER device may then operate in the micro-grid as a master deviceS3007 or slave device S3008.

For example, after a master device is identified S3005, slave devicesmay enter a mode S3008 whereby communications from the master device arerelayed as necessary, and one or more actions of slave devices areperformed by command of the master. As another example, master and slavedevices may update their individual grid databases accordingly. As moreGER devices interact with the master device, a negotiation algorithm,such as the exemplar algorithm shown in FIG. 30, may be repeated. Insome embodiments, an algorithm may include steps for the addition of GERdevices to an existing micro-grid. In some embodiments, a differentalgorithm may be used to add GER devices to a micro-grid in which amaster device has already been identified. In some embodiments, amicro-grid may be formed with a single master device. In someembodiments, a micro-grid may have more than one master device. In someembodiments, a micro-grid may have a master device for one or morespecific functions (e.g., communicating with an end user), and aseparate master device for other functions (e.g., communicating withother micro-grids, communicating with non-grid assets, such as policeand paramedic authorities). In some embodiments, a GER device declaredthe master in one negotiation may be declared as a slave during a laternegotiation, or even in a separate micro-grid.

The maximum number of micro-grid members can be defined by a pre-definedparameter or controlled by external circumstances such as availablegeneration and storage assets.

After formation of a micro-grid, the GER devices in the micro-grid maybegin grid operations. Grid operations may be in addition to one or moreongoing or normal GER device operations. A micro-grid may include one ormore grid operation algorithms. One of ordinary skill in the art shouldappreciate that numerous grid operations protocols are possible,depending on the nature, purpose, and responsibility of the micro-grid.

FIG. 31 illustrates a flow chart for one embodiment of a micro-gridoperation protocol. In the exemplar protocol, after micro-gridformation, GER devices may initiate grid operation protocol S3101. Thegrid operation protocol may be the same for all GER devices on themicro-grid, or the grid protocol may vary in whole or in part dependingon whether a GER device is a master device or a slave device. In theexemplar protocol in FIG. 31, the protocol determines whether the GERdevice is a master device or slave device. S3102. If the GER devicerunning the grid operation protocol is a master device, then that GERdevice may send a polling message to all member devices of themicro-grid S3108. The polling message may query whether, for example,the micro-grid is connected to or otherwise in communication with (e.g.,through one or more member GER devices) a central management agentS3109. If so, then the micro-grid may wait for and follow instructionsfrom the central agent (or other authorized source of instructions)S3110, and subsequently send out any commands or instructions to actS3111 based on instructions from S3110 (along with any otherinstructions from internal algorithms, for example). If the micro-gridis not connected to or otherwise in communication with a centralmanagement agent, then the micro-grid may apply internal rules and/oralgorithms S3112. One of ordinary skill in the art should appreciatethat such internal rules and algorithms may depend on the nature and/orpurpose of the micro-grid. For example, if the micro-grid is formed forsurveillance purposes, then the algorithm may include instructions formonitoring and recording audio and visual data. The master GER devicemay then issue instructions to other GER devices S3113.

If a GER device is a slave device in the micro-grid, then the slavedevice may determine whether a master device has sent a message S3103.The message may include a polling message, data, instructions, etc. Ifthe message includes or is a polling message S3104, then the slavedevice may provide its status to the master device S3105. Providingstatus to a master device S3105 may also include re-negotiating themaster/slave relationship, if necessary. The grid operation may providefor dynamic grid reforming based on various circumstances, such as, forexample only, a fault or authorized command. If the message includes agrid operation command S3106, then the salve GER device may process thecommand S3107. A command may be, for example, directions for powerrouting and distribution. A command may be, for example, a sequencedcold-start for consumers receiving power from GER devices on themicro-grid. One of ordinary skill in the art should appreciate that agrid operation command may include a wide variety of instructions, basedon, for example, the purpose of the micro-grid, current operatingconditions, instructions from a central agent, etc. The exemplaralgorithm shown in FIG. 31 is not meant to be limiting in any manner,but instead serve as a simple example of a grid operation protocol thatmay be performed by one or more GER devices in a micro-grid.

A micro-grid may provide numerous additional services to the utility,consumers, and third parties. For example, a micro-grid may be given thecapability of sharing communications capabilities between members. Forexample, one GER device in a micro-grid may be used to boostcommunications signals from another GER device in the same micro-grid.As another example, a single GER device may receive messages or otherdata from multiple GER devices, compile and then deliver such data. As aresult, a micro-grid may be used to reduce overall communicationstraffic. As another example, a micro-grid may be used to locally manageone or more GER devices, such as, for example, during periods whencommunications to the central management agent or other authority arelost, for instance, as a result of fault or deprioritizing.

In some embodiments, after GER devices form a micro-grid, one or moremember GER devices may form or update a membership database. Themembership database may include a variety of information, including forexample only, identification of master and slave devices, features andfunctionalities on one or more GER devices in the micro-grid, and whatcommunications links are available between members of the Micro-Grid andto any central management agent or other authority. In some embodiments,member GER devices may use a high level message passing scheme. Themessage passing scheme may be in addition to, part of, and/orindependent of, physical layer communications link types. For example,when a member GER device seeks to send a message to the centralmanagement agent, but does not have a direct link to the agent, that GERdevice may use a membership database to determine a communications routethrough the micro-grid, to the central management agent (or otherintended recipient). Destination, route, and source information may beencapsulated in the message, such that any intervening GER devices maydetermine whether the message is intended for that GER device, orinstead requires relaying along a route. In a similar fashion, when anycentral management agent or other authority seeks to send a message to amember GER device, but has no direct communications link to that GERdevice, then the agent may use a membership database to select a routefor relaying the message between other GER devices on the micro-grid tothe targeted GER device. In some embodiments, a GER device may receive amessage and a recipient, and determine a communications route to deliverthe message. In some embodiments, a grid protocol may includeinstructions for delivering a message to a targeted GER device, whichmay include determining a communications route. These methods mayconstitute a physical layer agnostic routing scheme based on high levelmessage passing.

In some embodiments, messages passed between micro-grid members maycontain an indication of priority. The priority may include multiplelevels, such that during reduced communications capability, a micro-grid(or an individual GER device) may prioritize passing of certain messagesover others. In some embodiments, a grid protocol may include astore-and-forward system for low priority messages. Such messages may bestored and transmitted after communications capabilities improve, forexample. Some messages may be deemed unimportant and deleted, based onfactors such as message priority, internal storage space, and time.

FIG. 32 shows an example of a micro-grid 3201. Within micro-grid 3201,master GER device 3203 and slave GER devices 3204 a-3204 c may beconfigured for using one or more direct communications links, such aspeer-to-peer communications, to communicate messages and data, includingMessage A and Message C, directly between GER devices. Member devices inmicro-grid 3201 may receive a message from a central utility managemententity 3202, and route the message to the ultimate or intendeddestination. For example, central utility management entity 3202 maytransmit Message C, intended for GER device 3204 b. However, GER device3204 b may not have a direct communications link with central utilitymanagement entity 3202. In some embodiments, central utility managemententity 3202 may transmit Message C to micro-grid 3201 withcommunications route information, and GER device 3204 a may receiveMessage C, decode the communications route information, and transmitMessage C to destination GER device 3204 b. In some embodiments, centralutility management entity 3202 may send Message C to the micro-grid3201, and the micro-grid 3201 or a GER device, such as GER device 3204a, may determine that Message C should be transmitted to GER device 3204b.

As another example, central utility management entity 3202 may transmitMessage A with the goal of GER devices 3204 b and 3204 c receiving themessage. Master GER device 3203 may receive Message A, and transmitMessage A to GER device 3204 c. GER device 3204 c may determine thatMessage A should also be transmitted to GER device 3204 b, based on, forexample only, instructions in Message A, additional instructions frommaster GER device 3203, or another grid protocol. Message A may includeinformation instructing GER device 3204 c to send Message B to aconsumer location, such as customer premises 3205. Alternatively,central utility management entity 3202 may have a separatecommunications link with customer premises 3205, and may use that linkto route Message B to GER device 3204 c. One of ordinary skill in theart should appreciate that the communications routes shown in FIG. 32are merely demonstrative, and that numerous configurations are possiblefor transmitting messages and data between GER devices and other sendersand recipients over a micro-grid. As shown in FIG. 32, a master GERdevice 3203 may serve as a communications hub for a micro-grid 3201communicating with a central utility management entity 3202. In someembodiments, any GER device in micro-grid 3201 may have an active rolein receiving and transmitting messages and data.

In some embodiments, a GER device may include data storage 3208 that maybe used for storing messages, data, and instructions. Database 3208 mayretain messages and data during communications outages, for subsequenttransmission. For example, if a communications path to the utilitycentral management entity 3202 is unavailable, or if a directcommunications path is not available, then database 3208 may storemessages and data for later retrieval or transmission. Alternatively, ifa separate utility-to-consumer communications path is present, then aGER device may utilize commercially available communications channels inorder to communicate with central utility management entity 3202. Asshown in FIG. 32, for instance, customer premises 3205 may have acommunications path with central utility management entity 3202 fortransmitting Message B. Micro-grid 3201 may be configured to use thatadditional communications route in certain situations, as should beappreciated by one of ordinary skill in the art.

One of ordinary skill in the art should appreciate that micro-grids maybe used to centralize data among GER devices, and as a result savecommunications bandwidth, and/or provide for continued communications inthe event of a loss of communications with a central utility managemententity 3202 or other authority. Embodiments may be configured to operateprotocols to establish of alternative communication routes. Alternativecommunications routes may include consumer-owned equipment andconsumer-purchased services, for example. Some embodiments may permitthe ad-hoc establishment of a peer-to-peer, message passing,communications networking scheme or schemes, between members of amicro-grid. Communications schemes may be agnostic of physicalcommunications links. Communications between GER devices, a centralutility management entity, and/or other distribution grid entities mayinclude embedded source, destination, and priority information. Suchinformation may be embedded in high level messages to allow messagerelaying the message and/or data to target destinations. Embodiments mayinclude protocols for delaying and/or dropping lower priority messagesin favor of higher priority ones.

Embodiments of a micro-grid may be configured to use one or moreprotocols for power load and supply management. For instance, amicro-grid may employ protocols to optimize source-to-load ratio. As anexample, a micro-grid may form because of a reduction of a distributiongrid's capability. In such a situation, it may become critical tooptimize the source-to-load ratio. Part of the optimization may involveassessing available resources and demands, and prioritizingdistribution, services, and other elements based on one or more factors,such as consumer need, emergency operation, and ultimate consequence.

FIG. 33 illustrates an example of load negotiation in a micro-grid 3301.Micro-grid 3301 may have previously formed, or may be formed during agrid formation event such as sudden power distribution interruption, asdescribed above. In this exemplar embodiment, micro-grid 3301 includesmaster GER device 3302 and slave GER devices 3304 a-3304 c. In thisembodiment, each GER device supports one consumer, customer premises3305 a-3305 d. Master GER device 3302 is in direct communication withcentral utility management entity 3302.

Micro-grid 3301, and/or the individual GER devices that form micro-grid3301, may operate one or more protocols for load and supply management.For example, upon power distribution outage, each GER device in amicro-grid may communicate with consumers to determine current andexpected load (Load Negotiation 1-4). GER devices may then report to themaster GER device 3302 what load reduction capabilities are available(Message A, B and C). The master GER device 3302 may use commands fromthe central utility management entity 3302 (Message D), and/or its otherrules and algorithms, to coordinate load reduction and power restorationcommands/requests (Message A, B and C). Protocols for load managementmay include a number of different techniques for managing the service,as one of ordinary skill in the art should appreciate. For example,master GER device 3302 may require some slave GER devices 3304 a-3304 cto eliminate power to their respective consumers. Alternatively, one ormore GER devices may be instructed to minimize load, or initiate one ormore load management protocols, such as shown in FIG. 10. In someembodiments, a GER device, such as master GER device 3302, maycontinually monitor and control other GER devices in the micro-grid3301. One of ordinary skill in the art should appreciate that amicro-grid may employ numerous methods for load negotiation andmanagement, based on various factors such as operating conditions,available power, back-up power, demand, and priority, for example.

A Micro-grid, or GER devices in a micro-grid, may be configured toperform a polling method to determine available power resources.Available power sources may include diminished power from a distributiongrid, power storage units, and power-generation units, for example.Embodiments of a polling method may determine load demands by consumersrelying on GER devices in the micro-grid. One of ordinary skill in theart should recognize that numerous prioritization algorithms may be usedto calculate available power and evaluate the most critical power needs.Such algorithms may be preprogrammed, re-flashed (by, for example, acentral management agent), or generated by a GER device.

Embodiments of the GER device may be configured to use rules andalgorithms stored in a database 3303 of one or more GER devices. Thedatabase 3303 may include rules and algorithms developed prior toinstallation, and rules and algorithms updated, revised, or added duringoperation. Such rules and algorithms may be updated and revised basedon, for example, system heuristics, modelling, utility procedures, andexternal conditions. The grid rules and algorithms may be coordinated bythe micro-grid, a central authority, a GER device, or a combinationthereof.

In some embodiments, after micro-grid formation, a GER device, such as amaster GER device 3302, may implement grid management using a set ofrules and/or algorithms 3302. Grid rules and algorithms may be updatedand revised as needed, such as by a central management authority, or aGER device. For example, GER devices may update grid rules andalgorithms through a download implemented over a communications link.The update may be triggered by, for example, conditions that dictate achange in the micro-grid behavior. The update or revisions may bespecific to a micro-grid, or applicable to all or a subset of GERdevices in a distribution grid. One of ordinary skill in the art shouldappreciate that there are numerous methods for providing updates to gridrules and algorithms. A GER device may report grid rules and algorithmsimplemented at a micro-grid level to the utility central managementsystem. The report may be at a higher level of control/reporting thanusual without grid formation, if, for example, communication isavailable. Grid rules and algorithms may be updated by the utilitycentral management system as appropriate. In some embodiments, adesignated GER device, such as a master GER device, may collect statusinformation and other data from GER devices in a micro-grid. In someembodiments, a GER device may collect data from other attached/monitordevices for reporting to the utility central management system.

If a Grid is, alternatively, operating independently (i.e. not undercentral utility management system control), that grid may be controlledvia any and all user interfaces of the Master Device (UI Message) tooverride internal Master embedded algorithms/rules (Grid Rules andAlgorithms Sub-Set). The embedded rules/algorithms can be updated at anytime by the central management agent but if the link to that agent isdown then the latest set are used by the Master Device.

One of ordinary skill in the art should appreciate that micro-grids maybe used for continued implementation of utility operating algorithms,even after communication loss with a central management agent, and alsoduring normal operation. Updated or revised algorithms for gridmanagement may be distributed through smaller independent algorithms, tobe implemented at the grid edge. Management of a distribution grid atthe grid edge may include communication between GER devices and acentral management agent. Messages may include high information content,but at lower frequency and/or bandwidth, as appropriate for theparticular communication. Further, authorized end users, such as utilitypersonnel, may manage GER devices and/or micro-grids through a userinterface included in, or attached to, one or more GER devices.

As will be appreciated by one of skill in the art, aspects or portionsof the present approach may be embodied as a method, system, and atleast in part, on a computer readable medium. Accordingly, the presentapproach may take the form of combination of hardware and softwareembodiments (including firmware, resident software, micro-code, etc.) oran embodiment combining software and hardware aspects that may allgenerally be referred to herein as a “circuit,” “module” or “system.”For example, measurements and subsequent calculations can be automated,using one or more software modules to characterize the device, recordresistance changes, calculate deflections, calculate device temperature,and/or calculate rate of heat accumulation or exchange. Furthermore, thepresent approach may take the form of a computer program product on acomputer readable medium having computer-usable program code embodied inthe medium. The present approach might also take the form of acombination of such a computer program product with one or more devices,such as a modular sensor brick, systems relating to communications,control, an integrate remote control component, etc.

Any suitable non-transitory computer readable medium may be utilized.The computer-usable or computer-readable medium may be, for example butnot limited to, an electronic, magnetic, optical, electromagnetic,infrared, or semiconductor system, apparatus, device, or propagationmedium. More specific examples (a non-exhaustive list) of thenon-transitory computer-readable medium would include the following: aportable computer diskette, a hard disk, a random access memory (RAM), aread-only memory (ROM), an erasable programmable read-only memory (EPROMor Flash memory), an optical fiber, a portable compact disc read-onlymemory (CD-ROM), an optical storage device, a device accessed via anetwork, such as the Internet or an intranet, or a magnetic storagedevice. Note that the computer-usable or computer-readable medium couldeven be paper or another suitable medium upon which the program isprinted, as the program can be electronically captured, via, forinstance, optical scanning of the paper or other medium, then compiled,interpreted, or otherwise processed in a suitable manner, if necessary,and then stored in a computer memory. In the context of this document, acomputer-usable or computer-readable medium may be any non-transitorymedium that can contain, store, communicate, propagate, or transport theprogram for use by or in connection with the instruction executionsystem, apparatus, or device.

Computer program code for carrying out operations of the presentapproach may be written in an object oriented programming language suchas Java, C++, etc. However, the computer program code for carrying outoperations of the present approach may also be written in conventionalprocedural programming languages, such as the “C” programming languageor similar programming languages. The program code may execute entirelyon the user's computer, partly on the user's computer, as a stand-alonesoftware package, partly on the user's computer and partly on a remotecomputer or entirely on the remote computer or server. In the latterscenario, the remote computer may be connected to the user's computerthrough a local area network (LAN) or a wide area network (WAN), or theconnection may be made to an external computer (for example, through theInternet using an Internet Service Provider).

The present approach is described with reference to illustrations and/ordiagrams of methods, apparatus (systems) and computer program outputsaccording to embodiments of the approach. It will be understood that thesteps described above, and the outputs, can be implemented by computerprogram instructions. These computer program instructions may beprovided to a processor of a general purpose computer, special purposecomputer, or other programmable data processing apparatus to produce amachine, such that the instructions, which execute via the processor ofthe computer or other programmable data processing apparatus, createmeans for implementing the functions/acts specified in the flowchartand/or block diagram block or blocks.

These computer program instructions may also be stored in anon-transitory computer-readable memory, including a networked or cloudaccessible memory, that can direct a computer or other programmable dataprocessing apparatus to function in a particular manner, such that theinstructions stored in the computer-readable memory produce an articleof manufacture including instruction means which implement thefunction/act specified in the flowchart and/or block diagram block orblocks.

The computer program instructions may also be loaded onto a computer orother programmable data processing apparatus to specially configure itto cause a series of operational steps to be performed on the computeror other programmable apparatus to produce a computer implementedprocess such that the instructions which execute on the computer orother programmable apparatus provide steps for implementing thefunctions/acts specified in the flowchart and/or block diagram block orblocks.

Any prompts associated with the present approach may be presented andresponded to via a graphical user interface (GUI) presented on thedisplay of the mobile communications device or the like. Prompts mayalso be audible, vibrating, etc.

One of ordinary skill should understand that the above description andthe Figures illustrate the architecture, functionality, and operation ofpossible implementations of devices, systems, methods, and computerprogram products according to various embodiments of the presentapproach. In this regard, each step in the disclosed embodiments andeach calculation and output may represent a block, module, segment, orportion of code, which comprises one or more executable instructions forimplementing the specified logical function(s). It should also be notedthat, in some alternative implementations, the functions in a block mayoccur out of the order noted in the figures. For example, two blocks insuccession may, in fact, be executed substantially concurrently, or theblocks may sometimes be executed in the reverse order, depending uponthe functionality involved. It will also be noted that each block, andcombinations of blocks in, can be implemented by special purposehardware-based systems which perform the specified functions or acts, orcombinations of special purpose hardware and computer instructions.

The terminology used herein is for the purpose of describing particularembodiments only and is not intended to be limiting of the approach. Asused herein, the singular forms “a,” “an,” and “the,” are intended toinclude the plural forms as well, unless the context clearly indicatesotherwise. It will be further understood that the terms “comprises”and/or “comprising,” when used in this specification, specify thepresence of stated features, integers, steps, operations, elements,and/or components, but do not preclude the presence or addition of oneor more other features, integers, steps, operations, elements,components, and/or groups thereof.

While the foregoing description references certain preferredembodiments, other embodiments are possible. Additionally, the foregoingillustrative embodiments, examples, features, advantages, and attendantadvantages are not meant to be limiting, as the devices, systems, andmethods disclosed herein may be practiced according to variousalternative embodiments, as well as without necessarily providing, forexample, one or more of the features, advantages, and attendantadvantages that may be provided by the foregoing illustrativeembodiments.

Accordingly, while devices, systems, and methods have been described andillustrated in connection with preferred embodiments, many variationsand modifications as will be evident to those skilled in the art may bemade without departing from the scope of the present approach, and theclaims should not be limited to the precise details of methodology orconstruction set forth above, as such variations and modifications areintended to be within the scope of the claims.

What is claimed is:
 1. An energy management device for placement on aportion of an electrical distribution grid downstream of a sourceconnection and upstream of an energy consumer connection, the energymanagement device comprising: (i) a primary electrical connectionterminal for receiving power from a source connection, the primaryelectrical connection terminal comprising a first voltage sensor and afirst current sensor; (ii) at least one secondary electrical connectionterminal for providing power to a consumer, the at least one secondaryelectrical connection terminal comprising a second voltage sensor and asecond current sensor; (iii) a modular electrical circuit layer inelectrical communication with the primary electrical connection terminaland the at least one secondary electrical connection terminal, theelectrical circuit layer in thermal connection with a heat exchangesystem for dissipation of heat generated by the electrical circuitlayer; (iv) an internal performance sensor for monitoring a performanceparameter of the device; (v) a controller layer configured to controlthe electrical circuit layer, the control layer comprising at least onecomputer processor and nonvolatile memory coupled to the computerprocessor in operable communication with the first and second voltagesensors, the first and second current sensors, and the internalperformance sensor, so as to receive an output signal from the first andsecond voltage sensors and the first and second current sensors and aninternal performance signal from the internal performance sensor; and(vi) a physical layer comprising at least one communication device inoperable communication with the controller layer; (vii) wherein thenonvolatile memory comprises computer program code embodied thereinthat, when executed by the processor, perform operations comprising: (a)receiving the internal performance signal; (b) comparing the internalperformance signal to a reference value; and (c) using the communicationdevice, transmitting to an end user data relating to the performancesignal following such comparing.
 2. The energy management device ofclaim 1, wherein the modular electrical circuit layer further comprisesa central DC power stage, and further comprising at least onebidirectional DC power connection port configured for electricalcommunication with a DC power resource, the at least one DC powerconnection port in electrical communication with the central DC powerstage.
 3. The energy management device of claim 1, wherein the modularelectrical circuit layer further comprises a central DC power stage, andfurther comprising at least one AC power connection port configured forelectrical communication with an AC power source, the at least one ACpower connection port in electrical communication with an AC-to-DC powerconverter, the AC-to-DC power converter in electrical communication withthe central DC stage.
 4. The energy management device of claim 1,wherein the device is configured for mounting on at least one of a pole,a pad, and a building.
 5. The energy management device of claim 1,further comprising an outer enclosure enclosing at least the modularelectrical circuit layer, the enclosure configured for mounting on atleast one of a pole, a pad, and a building.
 6. The energy managementdevice of claim 1, further comprising a meter for measuring load on thedevice, the meter in communication with the controller layer.
 7. Theenergy management device of claim 1, wherein further comprising acurrent sense connection socket configured for electrical communicationwith a current sense cable.
 8. The energy management device of claim 1,wherein the primary electrical connection terminal is connected to oneof an output of a distribution transformer and an output of a powersubstation.
 9. The energy management device of claim 1, furthercomprising a bi-directional direct current connection point configuredto receive power from a direct current source.
 10. The energy managementdevice of claim 1, further comprising an outer enclosure enclosing aninterior side of the heat exchange system, the outer enclosureconfigured for mounting to one of an electrical pole, a transformer pad,a transformer pad extension, and a building.
 11. The energy managementdevice of claim 1, wherein the modular electrical circuit layer furthercomprises at least one harmonics filter.
 12. The energy managementdevice of claim 1, wherein the communication device is configured toreceive data indicative of at least one of power provided to at leastone consumer, and power demanded by the at least one consumer.
 13. Theenergy management device of claim 1, wherein the communication device isconfigured to communicate with a second energy management device. 14.The energy management device of claim 1, wherein the computer programcode, when executed by the processor, performs operation comprising: (a)using the communication device, transmitting to the end user datarelating to the output signal; (b) responsive to a grid event, execute amanaging command; and (c) using the communication device, transmittingto the end user data relating to the output signal following executionof such managing command.
 15. The energy management device of claim 1,wherein the computer program code, when executed by the processor,performs operation comprising: (a) identifying a micro-grid formationevent; (b) using the communication device, transmitting a grid formationmessage to at least one other energy management device in communicationwith the energy management device; (c) using the communication device,receiving data from the at east one other energy management device; and(d) forming a micro-grid with the at least one other energy managementdevice.
 16. The energy management device of claim 15, wherein theoperations further comprise identifying a master energy managementdevice.
 17. The energy management device of claim 1, further comprisinga high-to-low voltage converter.
 18. The energy management device ofclaim 1, wherein the modular electrical circuit layer further comprisesa Power Factor Correction stage and a Voltage Regulation stage.
 19. Theenergy management device of claim 18, wherein the modular electricalcircuit layer further comprises at least one harmonics filter.
 20. Theenergy management device of claim 1, wherein the modular electricalcircuit layer further comprises a Power Factor Correction stage and aVoltage Regulation stage, wherein the Power Factor Correction stage andVoltage Regulation stage are disposed on opposite sides of a central DCpower stage, thereby providing harmonic isolation between the primaryelectrical connection terminal and at least one of the at least onesecondary electrical connection terminals.
 21. The energy managementdevice of claim 1, further comprising a Power Quality Meter, formeasuring power quality of the primary electrical connection terminaland the at least one secondary electrical terminal.